Post on 07-Nov-2021
Report to California Air Resources Board August 1988
Cost of Reducing Aromatics and Sulfur Levels in Motor Vehicle Fuels
Volume Ill -2
2Appendices i
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VOLUME III
APPENDIX COST OF REDUCING AROMATICS AND SULFUR IN MOTOR VEHICLE FUELS
SECTION PAGES
A GENERALIZED DESCRIPTION OF PETROLEUM REFINING AND THE ADL LP MODEL 20
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES 3
C REFINERY SURVEY LETTERS 18
D CHARACTERIZATION OF NEW PROCESS CAPACITY 7
E 1991 DIESEL RESULTS 28
F 1991 DIESEL AND GASOLINE COST EQUATIONS 5
G 1991 GASOLINE RESULTS 11
H 1995 DIESEL RESULTS 6
I 1995 GASOLINE RESULTS 4
J 1995 DIESEL AND GASOLINE COST EQUATIONS 5
K 1991 REFINERY EMISSION RESULTS 30
L 1995 REFINERY EMISSION RESULTS 9
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS 4
N NPRA SURVEY RESULTS _3
TOTAL 153
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A GENERALIZED DESCRIPTION OF PETROLEUM REFINING AND THE ADL LP MODEL
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APPENDIX A
1 LINEAR PROGRAMMING (LP) TECHNIQUE
The simulation of refinery processing in this study has been made using the Linear Programming (LP) technique LP is a mathematical technique which enables a large number of inter-relationships to be studied using computer technology to speed up the process of problem solving It is a technique which is highly suitable for the study of continuous process operations such as oil refining It is widely used by refiners to
o Plan refinery process capacity modificationsadditions and
o Plan refinery operations over various timeframes
In particular LP modelling can be used to monitor changes in refining operations as various parameters such as diesel aromatics and sulfur level are changed It can study changes in
o Direct fuel used for process heat (most refining processes use heat to achieve their objectives)
o Indirect fuel for steam raising
o Other energy requirements (eg electricity)
o Variable operating costs
o Existing process capacity utilization and
o New process capacity requirements
The LP technique derives an optimum solution to each individual problem by either maximizing or minimizing any pre-determined parameter It could therefore minimize energy maximize revenue minimize costs and so on For the purposes of this study we have used cost minimization to derive optimum solutions we believe that the cost minimization approach will produce results which are consistent with the day-to-day objectives of refiners
2 CATEGORIZATION OF INDUSTRY BY REFINERY GROUP
One major problem facing a study of this nature is the need to strike a balance between complexity and simplicity On the one hand simulation of each refinery would require an enormous work effort and conversely a single model simulation of the total refining industry would grossly underestimate the complexities of the refining situation
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In 1986 there were thirty operating refineries in California each with a slightly different configuration These variations lead to the use of different options to achieve more restrictive product qualities To analyze these differences and the cost associated with them we divided the thirty California refineries into six groups
We obtained information about the operation of California refineries through a confidential refinery survey
Based on the survey information we selected the following refineries for modeling
Group Description RefineryLLocation
I Topping None II Hydro skimming Kern Oil-Bakersfield III Conversion Unocal - Los Angeles IV Deep Conversion
- wo hydrocracking Shell - Wilmington V Deep Conversion
- LA Basin ARCO - Carson VI Deep Conversion
Northern CA Exxon - Benicia
Since topping refineries generally do not produce gasoline and produce only a small volume of diesel we chose not to model this refinery type We estimated the costs for this refinery type outside the LP model
We cannot provide a detailed description of the individual refinery models used in this analysis since this information is confidential We have however provided a generalized description of major refinery types and a generalized description of the Arthur D Little LP model below
3 DESCRIPTION OF MAJOR REFINERY PROCESS TYPES
A Process Unit Functions
Oil refineries are made up of a series of different process units Each refinery process unit can be classified as performing one or more of the following functions
o separation o conversion and o treating
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Separation involves a physical process (not a chemical process) which divides an oil into its component parts Distillation is the most frequent separation process used in refineries Distillation separates components by boiling range The first process in a refinery is generally an atmospheric distillation unit This unit separates crude oil into such components as naphtha kerosene gas oil and long residue These components are thus available for further processing in the refinery A simplified diagram of a crude distillation (separation) process is shown on Figure A-1 Separation processes include
o Atmospheric distillation o Vacuum distillation o Solvent extraction o Mole sieve separation o Cyrogenic separation and o Gravity separation
Conversion processes produce a chemical change in refinery components by altering the molecular structure of the components Fluid Catalytic Cracking (FCC) and Hydrocracking (HCC) break heavy long chain molecules found in resid into lighter components such as gasoline and distillates A simplified flow diagram of an FCC unit is shown on Figure A-2
Catalytic Reforming another type of conversion process converts low octane naphtha into high octane gasoline blendstock Reforming rearranges low octane naphthenes (cyclic compounds) into high octane aromatic compounds such as benzene and toluene Conversion processes include
o Fluid catalytic cracking o Catalytic hydrocracking o Thermal crackingvisbreaking o Coking o Residual upgrading o Alkylation o Polymerization and o Isomerization
Treating units remove impurities such as sulfur and nitrogen from refinery streams Treating can be used to improve the quality of a component prior to blending A component stream might also be treated before it is processed in a conversion unit This can be done to prevent catalyst poisoning andor to improve the quality of the products produced in the conversion process A simplified flow diagram of a catalytic hydrodesulfurization (treating) process is shown on Figure A-3 Treating processes include
o Hydrodesulfurization o Merox treating
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Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
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Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
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Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
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bull) I IJ SPEtltT CtTl_YST
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SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
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Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
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SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
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Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
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Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
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Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
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Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
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A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
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1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
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HYDROSKIMNING REFINERY
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CONVERSION REFINERY (SIMPLIFIED)
Gas
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Reformor (H-C Unlt) Gasoline
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identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
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Unit lli5Ullatci IJesulfurizntlon I
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Res lltl
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Resid Vacuum Resid
Unsat Gas
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or fuel ble11c1
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distillate dcsulf) FCC)
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The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
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consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
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Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
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26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
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Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
11l Arthur D Little Inc B--3
- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
VOLUME III
APPENDIX COST OF REDUCING AROMATICS AND SULFUR IN MOTOR VEHICLE FUELS
SECTION PAGES
A GENERALIZED DESCRIPTION OF PETROLEUM REFINING AND THE ADL LP MODEL 20
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES 3
C REFINERY SURVEY LETTERS 18
D CHARACTERIZATION OF NEW PROCESS CAPACITY 7
E 1991 DIESEL RESULTS 28
F 1991 DIESEL AND GASOLINE COST EQUATIONS 5
G 1991 GASOLINE RESULTS 11
H 1995 DIESEL RESULTS 6
I 1995 GASOLINE RESULTS 4
J 1995 DIESEL AND GASOLINE COST EQUATIONS 5
K 1991 REFINERY EMISSION RESULTS 30
L 1995 REFINERY EMISSION RESULTS 9
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS 4
N NPRA SURVEY RESULTS _3
TOTAL 153
A~ Arthur D Little Inc
A GENERALIZED DESCRIPTION OF PETROLEUM REFINING AND THE ADL LP MODEL
A~ Arthur D Little Inc
APPENDIX A
1 LINEAR PROGRAMMING (LP) TECHNIQUE
The simulation of refinery processing in this study has been made using the Linear Programming (LP) technique LP is a mathematical technique which enables a large number of inter-relationships to be studied using computer technology to speed up the process of problem solving It is a technique which is highly suitable for the study of continuous process operations such as oil refining It is widely used by refiners to
o Plan refinery process capacity modificationsadditions and
o Plan refinery operations over various timeframes
In particular LP modelling can be used to monitor changes in refining operations as various parameters such as diesel aromatics and sulfur level are changed It can study changes in
o Direct fuel used for process heat (most refining processes use heat to achieve their objectives)
o Indirect fuel for steam raising
o Other energy requirements (eg electricity)
o Variable operating costs
o Existing process capacity utilization and
o New process capacity requirements
The LP technique derives an optimum solution to each individual problem by either maximizing or minimizing any pre-determined parameter It could therefore minimize energy maximize revenue minimize costs and so on For the purposes of this study we have used cost minimization to derive optimum solutions we believe that the cost minimization approach will produce results which are consistent with the day-to-day objectives of refiners
2 CATEGORIZATION OF INDUSTRY BY REFINERY GROUP
One major problem facing a study of this nature is the need to strike a balance between complexity and simplicity On the one hand simulation of each refinery would require an enormous work effort and conversely a single model simulation of the total refining industry would grossly underestimate the complexities of the refining situation
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In 1986 there were thirty operating refineries in California each with a slightly different configuration These variations lead to the use of different options to achieve more restrictive product qualities To analyze these differences and the cost associated with them we divided the thirty California refineries into six groups
We obtained information about the operation of California refineries through a confidential refinery survey
Based on the survey information we selected the following refineries for modeling
Group Description RefineryLLocation
I Topping None II Hydro skimming Kern Oil-Bakersfield III Conversion Unocal - Los Angeles IV Deep Conversion
- wo hydrocracking Shell - Wilmington V Deep Conversion
- LA Basin ARCO - Carson VI Deep Conversion
Northern CA Exxon - Benicia
Since topping refineries generally do not produce gasoline and produce only a small volume of diesel we chose not to model this refinery type We estimated the costs for this refinery type outside the LP model
We cannot provide a detailed description of the individual refinery models used in this analysis since this information is confidential We have however provided a generalized description of major refinery types and a generalized description of the Arthur D Little LP model below
3 DESCRIPTION OF MAJOR REFINERY PROCESS TYPES
A Process Unit Functions
Oil refineries are made up of a series of different process units Each refinery process unit can be classified as performing one or more of the following functions
o separation o conversion and o treating
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Separation involves a physical process (not a chemical process) which divides an oil into its component parts Distillation is the most frequent separation process used in refineries Distillation separates components by boiling range The first process in a refinery is generally an atmospheric distillation unit This unit separates crude oil into such components as naphtha kerosene gas oil and long residue These components are thus available for further processing in the refinery A simplified diagram of a crude distillation (separation) process is shown on Figure A-1 Separation processes include
o Atmospheric distillation o Vacuum distillation o Solvent extraction o Mole sieve separation o Cyrogenic separation and o Gravity separation
Conversion processes produce a chemical change in refinery components by altering the molecular structure of the components Fluid Catalytic Cracking (FCC) and Hydrocracking (HCC) break heavy long chain molecules found in resid into lighter components such as gasoline and distillates A simplified flow diagram of an FCC unit is shown on Figure A-2
Catalytic Reforming another type of conversion process converts low octane naphtha into high octane gasoline blendstock Reforming rearranges low octane naphthenes (cyclic compounds) into high octane aromatic compounds such as benzene and toluene Conversion processes include
o Fluid catalytic cracking o Catalytic hydrocracking o Thermal crackingvisbreaking o Coking o Residual upgrading o Alkylation o Polymerization and o Isomerization
Treating units remove impurities such as sulfur and nitrogen from refinery streams Treating can be used to improve the quality of a component prior to blending A component stream might also be treated before it is processed in a conversion unit This can be done to prevent catalyst poisoning andor to improve the quality of the products produced in the conversion process A simplified flow diagram of a catalytic hydrodesulfurization (treating) process is shown on Figure A-3 Treating processes include
o Hydrodesulfurization o Merox treating
A-3
11~ Arthur D Little Inc
Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
I -a- t t-
7 I -- - middotl p_J t_ _ __ --
Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
t
- - -
Ah Arthur D Little Inc A-4
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
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Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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1l Arthur D Little Inc
Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
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C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
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hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
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12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
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1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
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11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
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IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
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11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
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1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
A GENERALIZED DESCRIPTION OF PETROLEUM REFINING AND THE ADL LP MODEL
A~ Arthur D Little Inc
APPENDIX A
1 LINEAR PROGRAMMING (LP) TECHNIQUE
The simulation of refinery processing in this study has been made using the Linear Programming (LP) technique LP is a mathematical technique which enables a large number of inter-relationships to be studied using computer technology to speed up the process of problem solving It is a technique which is highly suitable for the study of continuous process operations such as oil refining It is widely used by refiners to
o Plan refinery process capacity modificationsadditions and
o Plan refinery operations over various timeframes
In particular LP modelling can be used to monitor changes in refining operations as various parameters such as diesel aromatics and sulfur level are changed It can study changes in
o Direct fuel used for process heat (most refining processes use heat to achieve their objectives)
o Indirect fuel for steam raising
o Other energy requirements (eg electricity)
o Variable operating costs
o Existing process capacity utilization and
o New process capacity requirements
The LP technique derives an optimum solution to each individual problem by either maximizing or minimizing any pre-determined parameter It could therefore minimize energy maximize revenue minimize costs and so on For the purposes of this study we have used cost minimization to derive optimum solutions we believe that the cost minimization approach will produce results which are consistent with the day-to-day objectives of refiners
2 CATEGORIZATION OF INDUSTRY BY REFINERY GROUP
One major problem facing a study of this nature is the need to strike a balance between complexity and simplicity On the one hand simulation of each refinery would require an enormous work effort and conversely a single model simulation of the total refining industry would grossly underestimate the complexities of the refining situation
A-1
11~ Arthur D Little Inc
In 1986 there were thirty operating refineries in California each with a slightly different configuration These variations lead to the use of different options to achieve more restrictive product qualities To analyze these differences and the cost associated with them we divided the thirty California refineries into six groups
We obtained information about the operation of California refineries through a confidential refinery survey
Based on the survey information we selected the following refineries for modeling
Group Description RefineryLLocation
I Topping None II Hydro skimming Kern Oil-Bakersfield III Conversion Unocal - Los Angeles IV Deep Conversion
- wo hydrocracking Shell - Wilmington V Deep Conversion
- LA Basin ARCO - Carson VI Deep Conversion
Northern CA Exxon - Benicia
Since topping refineries generally do not produce gasoline and produce only a small volume of diesel we chose not to model this refinery type We estimated the costs for this refinery type outside the LP model
We cannot provide a detailed description of the individual refinery models used in this analysis since this information is confidential We have however provided a generalized description of major refinery types and a generalized description of the Arthur D Little LP model below
3 DESCRIPTION OF MAJOR REFINERY PROCESS TYPES
A Process Unit Functions
Oil refineries are made up of a series of different process units Each refinery process unit can be classified as performing one or more of the following functions
o separation o conversion and o treating
A-2
A~ Arthur 0 Little Inc
Separation involves a physical process (not a chemical process) which divides an oil into its component parts Distillation is the most frequent separation process used in refineries Distillation separates components by boiling range The first process in a refinery is generally an atmospheric distillation unit This unit separates crude oil into such components as naphtha kerosene gas oil and long residue These components are thus available for further processing in the refinery A simplified diagram of a crude distillation (separation) process is shown on Figure A-1 Separation processes include
o Atmospheric distillation o Vacuum distillation o Solvent extraction o Mole sieve separation o Cyrogenic separation and o Gravity separation
Conversion processes produce a chemical change in refinery components by altering the molecular structure of the components Fluid Catalytic Cracking (FCC) and Hydrocracking (HCC) break heavy long chain molecules found in resid into lighter components such as gasoline and distillates A simplified flow diagram of an FCC unit is shown on Figure A-2
Catalytic Reforming another type of conversion process converts low octane naphtha into high octane gasoline blendstock Reforming rearranges low octane naphthenes (cyclic compounds) into high octane aromatic compounds such as benzene and toluene Conversion processes include
o Fluid catalytic cracking o Catalytic hydrocracking o Thermal crackingvisbreaking o Coking o Residual upgrading o Alkylation o Polymerization and o Isomerization
Treating units remove impurities such as sulfur and nitrogen from refinery streams Treating can be used to improve the quality of a component prior to blending A component stream might also be treated before it is processed in a conversion unit This can be done to prevent catalyst poisoning andor to improve the quality of the products produced in the conversion process A simplified flow diagram of a catalytic hydrodesulfurization (treating) process is shown on Figure A-3 Treating processes include
o Hydrodesulfurization o Merox treating
A-3
11~ Arthur D Little Inc
Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
I -a- t t-
7 I -- - middotl p_J t_ _ __ --
Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
t
- - -
Ah Arthur D Little Inc A-4
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
A-5 11~ Arthur D Little Inc
Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
A-10
1l Arthur D Little Inc
Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
A-13
1~ Arthur D Little Inc
-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
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C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
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hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
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12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
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COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
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2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
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IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
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VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
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-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
APPENDIX A
1 LINEAR PROGRAMMING (LP) TECHNIQUE
The simulation of refinery processing in this study has been made using the Linear Programming (LP) technique LP is a mathematical technique which enables a large number of inter-relationships to be studied using computer technology to speed up the process of problem solving It is a technique which is highly suitable for the study of continuous process operations such as oil refining It is widely used by refiners to
o Plan refinery process capacity modificationsadditions and
o Plan refinery operations over various timeframes
In particular LP modelling can be used to monitor changes in refining operations as various parameters such as diesel aromatics and sulfur level are changed It can study changes in
o Direct fuel used for process heat (most refining processes use heat to achieve their objectives)
o Indirect fuel for steam raising
o Other energy requirements (eg electricity)
o Variable operating costs
o Existing process capacity utilization and
o New process capacity requirements
The LP technique derives an optimum solution to each individual problem by either maximizing or minimizing any pre-determined parameter It could therefore minimize energy maximize revenue minimize costs and so on For the purposes of this study we have used cost minimization to derive optimum solutions we believe that the cost minimization approach will produce results which are consistent with the day-to-day objectives of refiners
2 CATEGORIZATION OF INDUSTRY BY REFINERY GROUP
One major problem facing a study of this nature is the need to strike a balance between complexity and simplicity On the one hand simulation of each refinery would require an enormous work effort and conversely a single model simulation of the total refining industry would grossly underestimate the complexities of the refining situation
A-1
11~ Arthur D Little Inc
In 1986 there were thirty operating refineries in California each with a slightly different configuration These variations lead to the use of different options to achieve more restrictive product qualities To analyze these differences and the cost associated with them we divided the thirty California refineries into six groups
We obtained information about the operation of California refineries through a confidential refinery survey
Based on the survey information we selected the following refineries for modeling
Group Description RefineryLLocation
I Topping None II Hydro skimming Kern Oil-Bakersfield III Conversion Unocal - Los Angeles IV Deep Conversion
- wo hydrocracking Shell - Wilmington V Deep Conversion
- LA Basin ARCO - Carson VI Deep Conversion
Northern CA Exxon - Benicia
Since topping refineries generally do not produce gasoline and produce only a small volume of diesel we chose not to model this refinery type We estimated the costs for this refinery type outside the LP model
We cannot provide a detailed description of the individual refinery models used in this analysis since this information is confidential We have however provided a generalized description of major refinery types and a generalized description of the Arthur D Little LP model below
3 DESCRIPTION OF MAJOR REFINERY PROCESS TYPES
A Process Unit Functions
Oil refineries are made up of a series of different process units Each refinery process unit can be classified as performing one or more of the following functions
o separation o conversion and o treating
A-2
A~ Arthur 0 Little Inc
Separation involves a physical process (not a chemical process) which divides an oil into its component parts Distillation is the most frequent separation process used in refineries Distillation separates components by boiling range The first process in a refinery is generally an atmospheric distillation unit This unit separates crude oil into such components as naphtha kerosene gas oil and long residue These components are thus available for further processing in the refinery A simplified diagram of a crude distillation (separation) process is shown on Figure A-1 Separation processes include
o Atmospheric distillation o Vacuum distillation o Solvent extraction o Mole sieve separation o Cyrogenic separation and o Gravity separation
Conversion processes produce a chemical change in refinery components by altering the molecular structure of the components Fluid Catalytic Cracking (FCC) and Hydrocracking (HCC) break heavy long chain molecules found in resid into lighter components such as gasoline and distillates A simplified flow diagram of an FCC unit is shown on Figure A-2
Catalytic Reforming another type of conversion process converts low octane naphtha into high octane gasoline blendstock Reforming rearranges low octane naphthenes (cyclic compounds) into high octane aromatic compounds such as benzene and toluene Conversion processes include
o Fluid catalytic cracking o Catalytic hydrocracking o Thermal crackingvisbreaking o Coking o Residual upgrading o Alkylation o Polymerization and o Isomerization
Treating units remove impurities such as sulfur and nitrogen from refinery streams Treating can be used to improve the quality of a component prior to blending A component stream might also be treated before it is processed in a conversion unit This can be done to prevent catalyst poisoning andor to improve the quality of the products produced in the conversion process A simplified flow diagram of a catalytic hydrodesulfurization (treating) process is shown on Figure A-3 Treating processes include
o Hydrodesulfurization o Merox treating
A-3
11~ Arthur D Little Inc
Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
I -a- t t-
7 I -- - middotl p_J t_ _ __ --
Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
t
- - -
Ah Arthur D Little Inc A-4
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
A-5 11~ Arthur D Little Inc
Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
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C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
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hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
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12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
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1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
In 1986 there were thirty operating refineries in California each with a slightly different configuration These variations lead to the use of different options to achieve more restrictive product qualities To analyze these differences and the cost associated with them we divided the thirty California refineries into six groups
We obtained information about the operation of California refineries through a confidential refinery survey
Based on the survey information we selected the following refineries for modeling
Group Description RefineryLLocation
I Topping None II Hydro skimming Kern Oil-Bakersfield III Conversion Unocal - Los Angeles IV Deep Conversion
- wo hydrocracking Shell - Wilmington V Deep Conversion
- LA Basin ARCO - Carson VI Deep Conversion
Northern CA Exxon - Benicia
Since topping refineries generally do not produce gasoline and produce only a small volume of diesel we chose not to model this refinery type We estimated the costs for this refinery type outside the LP model
We cannot provide a detailed description of the individual refinery models used in this analysis since this information is confidential We have however provided a generalized description of major refinery types and a generalized description of the Arthur D Little LP model below
3 DESCRIPTION OF MAJOR REFINERY PROCESS TYPES
A Process Unit Functions
Oil refineries are made up of a series of different process units Each refinery process unit can be classified as performing one or more of the following functions
o separation o conversion and o treating
A-2
A~ Arthur 0 Little Inc
Separation involves a physical process (not a chemical process) which divides an oil into its component parts Distillation is the most frequent separation process used in refineries Distillation separates components by boiling range The first process in a refinery is generally an atmospheric distillation unit This unit separates crude oil into such components as naphtha kerosene gas oil and long residue These components are thus available for further processing in the refinery A simplified diagram of a crude distillation (separation) process is shown on Figure A-1 Separation processes include
o Atmospheric distillation o Vacuum distillation o Solvent extraction o Mole sieve separation o Cyrogenic separation and o Gravity separation
Conversion processes produce a chemical change in refinery components by altering the molecular structure of the components Fluid Catalytic Cracking (FCC) and Hydrocracking (HCC) break heavy long chain molecules found in resid into lighter components such as gasoline and distillates A simplified flow diagram of an FCC unit is shown on Figure A-2
Catalytic Reforming another type of conversion process converts low octane naphtha into high octane gasoline blendstock Reforming rearranges low octane naphthenes (cyclic compounds) into high octane aromatic compounds such as benzene and toluene Conversion processes include
o Fluid catalytic cracking o Catalytic hydrocracking o Thermal crackingvisbreaking o Coking o Residual upgrading o Alkylation o Polymerization and o Isomerization
Treating units remove impurities such as sulfur and nitrogen from refinery streams Treating can be used to improve the quality of a component prior to blending A component stream might also be treated before it is processed in a conversion unit This can be done to prevent catalyst poisoning andor to improve the quality of the products produced in the conversion process A simplified flow diagram of a catalytic hydrodesulfurization (treating) process is shown on Figure A-3 Treating processes include
o Hydrodesulfurization o Merox treating
A-3
11~ Arthur D Little Inc
Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
I -a- t t-
7 I -- - middotl p_J t_ _ __ --
Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
t
- - -
Ah Arthur D Little Inc A-4
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
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Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
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KTOftOG(N
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FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
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1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
A-19
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
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- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
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AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
Separation involves a physical process (not a chemical process) which divides an oil into its component parts Distillation is the most frequent separation process used in refineries Distillation separates components by boiling range The first process in a refinery is generally an atmospheric distillation unit This unit separates crude oil into such components as naphtha kerosene gas oil and long residue These components are thus available for further processing in the refinery A simplified diagram of a crude distillation (separation) process is shown on Figure A-1 Separation processes include
o Atmospheric distillation o Vacuum distillation o Solvent extraction o Mole sieve separation o Cyrogenic separation and o Gravity separation
Conversion processes produce a chemical change in refinery components by altering the molecular structure of the components Fluid Catalytic Cracking (FCC) and Hydrocracking (HCC) break heavy long chain molecules found in resid into lighter components such as gasoline and distillates A simplified flow diagram of an FCC unit is shown on Figure A-2
Catalytic Reforming another type of conversion process converts low octane naphtha into high octane gasoline blendstock Reforming rearranges low octane naphthenes (cyclic compounds) into high octane aromatic compounds such as benzene and toluene Conversion processes include
o Fluid catalytic cracking o Catalytic hydrocracking o Thermal crackingvisbreaking o Coking o Residual upgrading o Alkylation o Polymerization and o Isomerization
Treating units remove impurities such as sulfur and nitrogen from refinery streams Treating can be used to improve the quality of a component prior to blending A component stream might also be treated before it is processed in a conversion unit This can be done to prevent catalyst poisoning andor to improve the quality of the products produced in the conversion process A simplified flow diagram of a catalytic hydrodesulfurization (treating) process is shown on Figure A-3 Treating processes include
o Hydrodesulfurization o Merox treating
A-3
11~ Arthur D Little Inc
Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
I -a- t t-
7 I -- - middotl p_J t_ _ __ --
Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
t
- - -
Ah Arthur D Little Inc A-4
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
A-5 11~ Arthur D Little Inc
Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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1~ Arthur D Little Inc
hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
A-19
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
11l Arthur D Little Inc B--3
- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
Figure Al
SEPARATION PROCESSES FRACTIONATION (DISTILLATION)
DETAIL OF ~ ~ D__j7BU88LE CAP
I -a- t t-
7 I -- - middotl p_J t_ _ __ --
Other Separation Processes
Extraction (Solvent) Mole sieve Cyrogeni c Gravity
SOURCE Our Industry Petroleum pp 230 The British Petroleum Co Ltd 1977
t
- - -
Ah Arthur D Little Inc A-4
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
A-5 11~ Arthur D Little Inc
Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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1l Arthur D Little Inc
Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
A-Hi
1~ Arthur D Little Inc
hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
A-19
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
11l Arthur D Little Inc B--3
- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
Figure A2
CONVERSION PROCESSES FLUID CATALYTIC CRACKING UNIT
H ~ 1
I
I
~~ STAIPP1NG S7(ampL1
bull) I IJ SPEtltT CtTl_YST
ti ralSTpound pound47 ~T 10bull1E-
I I
1~~ Yl L~l - -----~~---------~8 l ~ j ~--~---
t_____________SaLIJ~A~Y==-=-~--l_o~________
FIG _74_ FCC UCil Model m
SOURCE Gary and Handwerk pp 93 Petroleum Refining Technology and Economics JH Gary and GE Handwerk Marcel Dekker 1975
OTHER CONVERSION PROCESSES
Catalytic Hydrocracking Thermal cracking (vis breaking) CokingResidual upgrading Catalytic refonning A 1 kylation Po lymeri za ti on Isprneri za ti on
r
I
A-5 11~ Arthur D Little Inc
Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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1l Arthur D Little Inc
Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
A-13
1~ Arthur D Little Inc
-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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1l Arthur D Little Inc
centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
A-Hi
1~ Arthur D Little Inc
hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
A-19
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
11l Arthur D Little Inc B--3
- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
Figure A3
TREATING PROCESS - CATALYTIC HYDRODESULFURIZATION
MTQQQG[W R[CYCL[
4 o----
to _)
700-~
TO 80Clt
i ---
I I
cw---I
ZS bull
~
~ ~ SOU~ t
WAT[ltgt
S7(AW oP MOT OIL100
KTOftOG(N
S(PAbulllTOtt
FIG 6 1 Catalytic bydrodeaulfllruer
SOURCE Gary and Handwerk P 115 Pefroleum Refining Technology and GE Handwerk Marcel Dekker 1975
Other Treating Processes
Merox Caustic Acid Clay Amine Sulfur Recovery
1~ Arthur D Little Inc A- 6
Economics JH Gary and
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
A-10
1l Arthur D Little Inc
Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
A-13
1~ Arthur D Little Inc
-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
A-15
1l Arthur D Little Inc
centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
A-Hi
1~ Arthur D Little Inc
hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
A-19
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
11l Arthur D Little Inc B--3
- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
o Caustic treating o Acid treating o Clay treating o Amine extraction o Sulfur recovery and o Desalting
All refinery process units are made up of combinations of the above three process types
B Refinery Configuration Types
Refineries can be divided into four configuration types based on the process units present the four configuration types are
o Topping o Hydroskimrning o Conversion and o Deep conversion
These refinery types are given in order of increasing complexity Each successive configuration type includes the same processes as the preceding type and adds one or more additional distinguishing process Figure A-4 provides a summary of the basic characteristics and distinguishing processes for each of these configurations
An increase in refinery complexity enables the refinery to process the same barrel of crude oil into a greater yield of light and valuable products A complex conversion or deep conversion refinery is able to produce gasoline and diesel at the expense of low value residual fuel However the greater the complexity the higher the investment cost maintenance cost and manpower requirements
1 Topping Refinery
The simplest refinery configuration is topping A topping refinery uses a separation process--atmospheric distillation--to separate crude into its natural fractions LPG and lighter naphtha kerosene distillate and long resid A simplified process flow diagram for a typical topping refinery is shown on Figure A-5 California Group I are topping refineries
A topping refinery consists of a crude desalter and an atmospheric distillation tower Although not shown a topping refinery might also have a vacuum distillation unit which further distills long resid into vacuum gas oil and short resid Vacuum gas oil can be sold as cracker feedstock or for lube oil blending Short resid may be sold as asphalt Long resid (or short resid) would normally be cut (ie blended to meet viscosity) with distillate to produce residual fuel
Amiddot-7
1~ Arthur D Little Inc
Figure A4
PRINCIPAL TYPES OF REFINERY CONFIGURATIONS
Basic Process CharacteIistics
Distinguishing PJQ~ess Units
gt I
co
Topping (Distillation) Hydro skimming
bull Most simple bull Adds capability configuration to produce gasoshy
line from naphtha bull Breaks crude into
natural fractions bull Earns naphthagasoshyline differential
bull Produces naphtha instead of finishshyed gasoline
bull Distillation bull Reformer column
bull Vacuum unit possibly
Conversion
bull Converts lighter fuel oils to light products
bull Earns partial heavylight product price differential
bull Catalytic cracking
Coking (Deep Conversion)
bull Converts all fuel oil to light and middle products
bull Earns full heavy light product price differential
bull Coking
A~ Arthur D Little Inc
Figure A5
TYPICAL TOPPING REFINERY
Volume 000 B0
C amp light er
Crude Crude
4
Naphtha ~
Jet Kero c
uo t
QJ deg Cr-Or-ltll t 0 QJ E ltll 3 micro 0 Cl Cl I-
lt
Distillate
-
desalting
Long Resid
1~ Arthur D Little Inc A-9
A topping refinery cannot directly produce gasoline since the octane quality of naphtha is quite low In countries where significant lead (TEL) blending is allowed a low octane gasoline product can be produced from naphtha
2 Hydroskimming Refinery
Hydroskimming refineries are one step more complex than topping units A simplified diagram for a typical hydroskimming refinery is shown in Figure A-6 The first two process units in this refinery- -crude desalting and distillation unit--are identical to those in a topping refinery The distinguishing process in a hydroskimming refinery is the catalytic reformer California Group II are hysdroskimming refineries
A reformer is a catalytic process which upgrades naphtha into gasoline quality material The crude naphtha must be treated in a naphtha pretreater to remove sulfur and nitrogen which would otherwise poison the reformer catalyst
Figure A6 also shows three other process units which may or may not be present in a hydroskimming refinery These units are isomerization distillate desulfurizing and vacuum distillation
An isomerization unit converts the lightest naphtha fraction into gasoline quality by converting straight chain hydrocarbons into isomers (ie branched hydrocarbons) Isomerization units are popular in countries with lead phasedown requirements The light straight run naphtha would be blended to gasoline even if an isom unit was not available
The need for a distillate desulfurizing unit is set by the sulfur specification of the distillate product and the crude oil being processed The distillate produced from sweet crudes (ie low sulfur) may not require desulfurization to current specifications However sour crudes especially when processed in locations with stringent distillate sulfur specs would require desulfurization
The vacuum distillation unit would be included in a refinery if the vacuum gas oil had a more profitable alternative than residual fuel blending such as lubricating oils or feedstock to more complex (conversion) refineries Vacuum distillation is also required to produce asphalt
Hydroskimming refineries cannot produce more light product from a crude than is naturally available These refineries simply have the capability of upgrading the naturally occurring naphtha in the crude to gasoline
3 Conversion Refinery
A simplified process flow diagram for a typical conversion refinery is shown in Figure A-7 The processes shown outside the dashed lines are
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1l Arthur D Little Inc
Figure A6
I f- f-
Crude Crude
I Desalting
Gas Plant
Refinery Fuel
1---- -i- - isomer za7
1Light Straight Run Gasoline j tion to Gasoline I __ _unit_ J blend
I Naphtha I Naphtha Pretreater
Reformer to Gasoline
blend
Distillation
Unit rDist7Uate - -
I J1111g1-e D lf ___i tmiddot I ___ _ _bull esu ur za ion
Atmospheric I
Resid --- - - VGO I 1-----f-
Vacuum II-----a ~-~middotI
I I Vacuum f- C 1 I D i ( 0 shy
L----l t- Cfh f-f-Resid
HYDROSKIMNING REFINERY
1~ Arthur D Little Inc
___ ____________
Figure A7
CONVERSION REFINERY (SIMPLIFIED)
Gas
I t~ ~ (Refinery ~el) To H2 Pinnt LPGCat ~
Reformor (H-C Unlt) Gasoline
n I
Topping
I I- h)
Crudu Oil
_____
I
Naphtha Minus H2 Keroseno
Kerosene Kero Hydro ~
(
Diesel J
Treat I bull
H2 Gas
LPG
Diesel Oil L Diesel Hydro
Treat r--- -bull- bull-bull-4-- --7r- ______ _J
I Gas fl 2
Plant H2 ICoiivarsion
I (H-C only) Cat Crocking
shyGasoline
Kerosene
Diesel OilI I I I I I
Vac Dist
Voe Gas Oil
~
or Hydromiddot
Cracking
Cutter Stacie
I
L- Conversion InsideI
I I
Dashed Line
I I I
7
7
I I
f Short Residue j 1
j________ Rerinory Fuel I
Fuel Oi
L - --1 A~ Arthur D Little Inc
identical to those for a hydroskimming refinery The distinguishing process is the conversion unit shown inside the dashed line California Group III are conversion refineries
The conversion process can either be an FCC unit a hydrocracking unit or a thermal cracking unit In each case the vacuum gas oil (VGO) which would otherwise go to residual fuel is cracked into lighter products
An FCC unit uses a fluidized catalyst at high temperatures to crack the VGO into lighter products An FCC unit does not fully convert the feed to lighter products The residual or uncracked portion is shown here as cutter stock The sulfur in the VGO feed to an FCC unit remain in the conversion products which require further treatment for sulfur removal
A hydrocracking (HCC) unit operates under extremely high pressure in the presence of hydrogen to upgrade all the VGO into light products In California some cracked distillates are also generally input to the HCC to produce Jet Fuel and Gasoline The products from an HCC unit are extremely low in sulfur and require little further treatment
A thermal cracking unit is less severe than either of the above processes and only converts a portion of the VGO into lighter products As in the case of the FCC unit the products require further treatment for sulfur removal
In a conversion refinery the short residue or vacuum tower bottoms is blended to fuel oil or sold as asphalt FCC cutter stock or distillate is used with the short residue to produce an acceptable viscosity fuel
4 Deep Conversion Refinery
Deep conversion is the most complex form of refinery configuration A deep conversion refinery converts all reridual fuel components into lighter more valuable products and coke California Groups IV V and VI refineries are in this category
Figure A-8 is a simplified flow diagram for a typical deep conversion refinery The flow diagram is the same as a conversion refinery except for the addition of the coker In this particular drawing the VGO conversion process is shown as an FCC unit A hydrocracking unit could be substituted as the VGO conversion process The alkylation unit however would only be suitable with an FCC since it requires light olefin (unsaturated compounds) feedstock which is produced from FCC units but not HCC units California Group IV refineries have only a FCC unit California Group V and VI refineries have both a FCC operation on VGO and HCC unit operating on cracked distillates
Coal-like substance produced in a delayed coking process
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-Figure A8
RefiD_erv futllll -middot --- ----- Gas Plant
I ~
LE
r- - - -
lisomeri7il1 u~lit straight run gasoline ltion unitl to gilsoline blend L___ ~
gt I
I- -I-- Alkylate ( t ()
il pll t Ila Naph tlw
Reformer Reformimiddotr 1------l~-(~iln I it1lt h l ind Igt-
lctfsbull~
Dist i I lH i(1n 1-----
1 DistiJlatc l ------- lc-tincrv Fuel (tn II() Normal Rutanc
Unit lli5Ullatci IJesulfurizntlon I
L------
Atmospheric
Res lltl
Vacuum
Resid Vacuum Resid
Unsat Gas
Plant
rec
Tso-bu_nne Olefins
Alkylatio1 Unit
FCC Gc1sollncto gasoline blend)
~~cle Oil_to distillate
lleavv J~yc le Ui 1tJ to f ucl
Gases (to unsat gas plant)
Lt coker Coker I llv coker
_ ~ ~ middotmiddot-middot gas oi 1 eJ tol IHv coker gas oil ~ to
gnsol 1 _ 1
CrudeCrude
IJesnlting
or fuel ble11c1
h lend)
gasolin~(to gasoline blend) gasolinoSto naphtha pretreater)
distillate dcsulf) FCC)
I
Coke
DEC CUNVERS 10N REFINFRY -- -middotmiddot - ---------- ---------fl Arthur D Little Inc
The coker uses the heaviest portion of the crude--vacuum resid--as its feedstock The coker produces light coker gasoline which is blended directly to gasoline The heavy coker gasoline is treated and reformed to improve its octane Light coker gas oil is either a distillate blendstock or can be upgraded to gasoline on an FCC unit The heavy coker gas oil is further upgraded in either the FCC or HCC conversion process The coker products require treating to remove sulfur
Coking units also produce coke which is a solid coal-like material Coke can be used in a blend with coal in utility boilers Coke is also used in the production of cement and to produce electrical anodes
Deep conversion refineries do not produce a residual fuel product Coking refineries with FCC units may sell their cutter stock (heavy cycle oil) to others who blend residual fuel
The isomerization and distillate desulfurizing units shown in Figure 8 are optional uni ts in any type of refinery An isom unit would be built at a refinery short on octane A refiners decision to use a distillate desulfurizer is based on crude slate and distillate product specifications
Summary
There are three basic refinery processes functions separation conversion and treating All refinery process units combine of one or more of these basic process functions
There are four refinery configuration types which are distinguished from one another by the process units they contain The simplest refinery types are topping and hydroskimming which yield products at the level naturally available from the crude Hydroskimming is distinguished from topping by its reformer which allows the refinery to produce gasoline rather than naphtha
Conversion and deep conversion refineries convert the heavier fractions of the crude oil into lighter products Conversion refineries upgrade the vacuum gas oil portion of the crude Deep conversion refineries convert both the vacuum gas oil and vacuum resid into lighter products and coke Conversion refineries are able to earn part of the heavylight product price differential Deep conversion refineries are able to earn the full differential between light and heavy products
4 middot The Arthur D Little Refinery LP Model
Model Description
Over the past several years Arthur D Little has developed large-scale computer models for simulating the major world refining
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1l Arthur D Little Inc
centers In such models a specified product demand pattern is met by a specified crude slate in an optimized refinery operation An analysis of model outputs offers valuable insight into crude and refined product values with respect to the stated cost of a reference crude oil In effect the model continuously answers the question What will it cost to produce an additional barrel of Product X and What would an additional barrel of crude oil Y be worth relative to the reference crude oil and the other crude oils in the crude oil slate
A simplified refinery flow sheet shown in Figure A9 represents one of the models This particular one is of a US West Coast cluster model and was used in a study of the cost of lead phase-down and sulfur content reduction of gasolines for the Environmental Protection Agency (EPA-4503-76-016 a and b) This particular model was not used in the current study which was based on confidential refinery specific models
The main blocks of the refinery processing scheme can be broken down into (1) naptha (b) gas oil and (c) residual The full-range (C
5 - 375degF) untreated naphtha can be sold directly Otherwise the naphtha is split into several fractions for blending or further processing The light (200-340) and heavy (340-375) naphthas can each be hydrotreated Each hydrotreated naphtha can be routed to a catalytic reformer with the option of running at three different octane severities The model chooses the optimum severity or it can bypass some naptha into finished product blending
The gas oil processing scheme is less complex than the naptha The full-range 375-650deg F fraction can be split into a kerosene fraction and heavy gas-oil fraction and each stream can be subsequently hydrotreated
The residual fraction (atmospheric bottoms) can be directly blended to residual fuel oil or desulfurized before blending if from a sour crude origin It can also be fed to a vacuum distillation unit the vacuum overhead stream can then be hydrotreated for fuel-oil blending or fed to a FCC or HCC for conversion into lighter products The model is allowed the option of choosing between two catalytic cracking conversion levels or several grades of vacuum gas oil feed the propylene-butylenes from catalytic cracking can be fed to an alkylation unit or to a polymerization unit to make gasoline blending stocks Vacuum bottoms can be routed to a coker to reduce the production of fuel oil and to produce some lighter products and coke The coker naphtha can be hydrotreated and the heavy fraction reformed The coker gas oil can also be hydrotreated and the heavy fraction cracked
Additional processes in the model not shown on this refinery flow sheet include a hydrogen plant (If the volume of hydrogen required for treating exceeds that supplied from catalytic reforming then
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1~ Arthur D Little Inc
hydrogen must be manufactured either from refinery gas naphtha andor residual fractions) The refinery is usually required to generate its own steam and power although these can be variable options A sulfur plant is provided which converts hydrogen sulfide into elemental sulfur
ADL has accumulated industry data for each processing unit for each crude oil This includes yields and key properties of the products from that particular process capital costs and operating costs divided into the following seven categories refinery fuel consumption steam water electric power catalysts and chemicals operating labor and maintenance The capital and operating costs for each refinery process unit are based on modern units of the size consistent with each selected refinery process unit capacity
The costs of offsites for crude handling and product blending and storage is included and varies with crude distillation capacity An internal refinery fuel balance is maintained ( including fuel needed for steam generation power generation etc) with a maximum sulfur content specification
Economic Basis
The data supplied to the model for the computer runs consists of
0 Product demands and specifications 0 Crude supply and 0 Refinery processing options for each crude
Product demands were fixed volumes which must be met in this study However we can allow product volumes to optimize at specified netbacks sometimes limiting minimum or maximum levels
The basic assumption underlying our use of fixed product demands is that the total market for petroleum products in a refining center is relatively inelastic to changes in product prices This is most true for products such as gasoline and jet fuel which have no competitive supply source Heating oil and residual fuel have had inter-fuel competition from natural gas and coal in the past One result of this is that residual fuel has been sold below its investment cost value If we expect this condition to continue we can remove the fixed volume restriction for residual fuel oil and allow it to seek its own optimum production level at an inter-fuel competitive price structure
In a multi-crude system crude slate is usually 2pecified as a fixed supply for all crudes except a marginal crude in which must be allowed to vary in order to meet a fixed product slate because it is not known in advance the exact volume of crude oil that will be required due to gainslosses from refinery processes and own fuel
2 Alaskan North Slope crude is the marginal California crude
11~ Arthur D Little Inc
consumption The volume of the marginal crude consumed will vary somewhat from run to run A delivered price is assigned to this reference crude and all other crude and product values are determined relative to the reference crude oil price chosen
For each refinery process in the model the capital cost is supplied plus several categories of operating costs The capital cost is converted to a daily cost basis via a capital recovery factor The capital charge provides for depreciation income tax property tax and insurance and profit Other cost categories can be selectively included or excluded so that the model can represent operations under variable cost cash cost or fully built up cost conditions
The linear programming algorithm will optimize the refinery processing scheme at minimum cost to meet the required product demands and product specifications from the crude slate provided It is assumed that complete interchange of intermediate streams from all crudes is possible
The most useful outputs from the linear programming runs are the optimum refined process schemes chosen for each crude oil and the shadow prices for the refined products and crude oils These shadow prices indicate the internal refinery values for each respective product and each crude oil and indicate the minimum long-term selling price that a particular product requires in order to justify capital expenditures for its manufacture or the maximum long-term purchase price for each crude oil The product values (sometimes called investment cost values) are often used to major oil companies as transfer values when transferring products from refining to marketing divisions and also from refinery to petrochemical divisions
The relative crude values simulate the internal crude oil values assigned by large integrated oil companies which have the flexibility to reallocate crudes among various refineries to optimize its operations in a large geographic region
In parametric evaluations we systematically vary certain key uncertainties in our input data (such as product demand levels specifications operating costs crude supply patterns etc) to test the flexibility of model outputs to these changes A parametric evaluation consists of an alternate unique LP solution for each variation in input data We can thus evaluate on a quantitative basis the extent to which a variation in a particular input forecast will affect the conclusions in particular gasoline and diesel quality in this analysis
It is important to emphasize that the crude and product values generated by the refinery simulation model are costs and not prices Market constraints can and do limit the extent to which a refinery can recover the costs allocated to each product in the model However the model does show when additional costs are incurred in making more
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1~ Arthur D Little Inc
of a particular product It indicates a lower market value for high-sulfur crude oils and a higher market value for low-sulfur crude oils as the demand for low-sulfur products increases The crude oil values are not prices but replacement values that is the value at which a refiner would replace a barrel of the reference crude with the barrel of another crude oil A high replacement value for a given crude oil means that the refinery can reduce refining costs by substituting this crude oil for a low replacement value crude oil
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----- ----
-J--
Figure Abull~ WEST COAST CLUSTER MODEL CALIBRATION
(MBCD) 1110675-2 j7 )
10~ C ID 1~bull3 04 t O ------ Rltfinoy Ga to 2ampidegF c 1602ocidegF 1 - Ml--_(FOEI ySphnef 5 I Aefomne 22 40 _
l 6369 3652 Pr1n11um
1 I -
CJB 88 r--------i Gaiolrrnt
Uiu-Jyuc J012R19Jlu-----A--- Raflm11e PurchaMd Natu11f Ga1olme bull i 99
130 0 86 RefOfmer ltrommu I 49 NC 408 Pool ~ ~ N~th a 28 94 23 9b 37 27 lJ1trac11on 5= - _middot e- SJ Unleaded
26 camp Sp1t1bull 1759 JOOJ40of ~ 1941rom ---- ---______ 390 BTX J90BRXf) CrudM Li~tar _______ 4 17 340 375degF ~ - - - Ttirufer M J 38 C11iloni1 ~ - --bull--~ 5800
Oe~ullu11ad Hlavy Nplllhil 78 California J - J VenturI 21~ AlrnctiPhtlic 31 77 Full R1ng1 NilPhrtw Jl J Bl 381 Naphthi r-
Oistillat10n ~ 11~ 3870Ga0i137510650degF ---~--------+-------- __________ ____J_~~
r_
lndonesNn 102( ~ O~llur1zed L1gh1 G~ 011 ______ _______5_1_8 ~ IBamp9 Jrt flHII -
Atabian laquo-~ ___ Orf -==_J=-~~I--- - - --- -- - ~~ ~d~~laquolute ------ middot-- - - -~ f---- 4221 D1st1ll1te__ 14 aG~wt 17 Kerltlalln9
Gas Oil 22 11 Hydro I Heavy Hydrocriekile I Pool 1218 ~ Sphttff Crcker r S B6 2215 Oi-ttillau F~
Bonom 3091 Hea-y Hydocr1ekld Jet fuef 1391 Oilho----~ 650 t degF Gn O1J 5-00-650oF HWj ltibull Oil 4 47 -
217I ______16701 -----------~ j 21ri---7 091UUume-dHe__GsO11 -N HOU
Vtcuum CMld From Turnsflr C1C C-C 1-lfl 130 M1ud Oltfirr0 650-1050degF ~ ~ I pt Naphth1 C4 t J Alltylitl fgt 5~ 10 Pt1r~
------ ~ - ~ I ~ - j I AlltylilJon -----~
~ SJ02 ri I Lr~t Cycle 011 ________lil S6
~ 1 I C1t1lyt1c ~ ~acuum ~ t Crcite- Ctbullif1MJ 011 IO 50 1 3055 RaidJlI F~
Lta 0111= ~ JSOl - ~ Oil
oi ______~ J 15 __
-------------middot- ___________________ _________ VlcUum Owem-i __~9~-1-f-----nll~
I Bottoms 1080 +degF ------lt----- VillC l1oncrns 6 68 ~ I ~ 202 Alphalt _
2916 C3C4~---~--middot-----~ i---~---- - -- ~ - __middot_middot-_-_-__middot_middot_ 36Lubes -
I J _lr~SokerNiflhlhbull __ ~------- __________ middot---- __4~ -
- Me-J Co~ler l R t ~ ~ I I HOU 7 4~ I I J4 e bullnerv 14J(l5 IFOEJ _
I ~- -- middot-middot--shy--L------------~bullI Coke1 i~-1 nu fOEJ Fuei bull
39 431 ccFOEI 1349 __ -~PurchaK1iC~Alkyl1t~ _ Coke 958 t090 ionsj
Cob __ _~nCL- __ _ 1 555-4 E-ernentt_ ___9 82 so from FCC
Su-ttur ITCWlI)IUampP-NndegGlaquos 1423 SOFtsulfur Recov~ 4348~Emi
ITonsJ21455-0x FRefinery fuel _ 194 A~ fNd trcn ~~ _
_ 1e0C_NdlTomTrws_ __
1~ Arthur D Little Inc
~-
B CHARACTERIZATION OF 1986 CALIFORNIA REFINERIES
1~ Arthur D Little Inc
1986 CA Refinery Groups
Group 1 Topping(l)
Conoco Santa Maria Edgington Long Beach Witco Chemical (Golden Bear) Oildale MacMillan Signal Hill Oxnard Oxnard San Joaquin RFG Bakersfield Huntway RFG Benicia Huntway RFG Wilmington Gibson Oil Bakersfield
Subtotal Operating 9
Shutdown
Demenno-Kerdoon Compton ECO Signal Hill Gasco Anchor Lunday Thagard South Gate Western Oil amp RFG (Marlex) Long Beach West Coast Oil Bakersfield Golden Eagle Carson
Subtotal Shutdown 7
Total Refineries in Group 16
Group 2 Hydroskimming(l)
Beacon Hanford Kern County Bakersfield Newhall RFG Newhall Paramount (old Conoco) Paramount Sunland Bakersfield
Subtotal Operating 5
Shutdown
Chevron Bakersfield USA Petrochem Ventura
Subtotal Shutdown 2
Total Refineries in Group 7
1~ Arthur D Little Inc B-1
1986 CA Refinery Groups (Continued)
Group 3 Complex-Without Coking
Chevron Richmond Fletcher Carson Golden West Santa Fe Spr Pacifi~ RFG Hercules
ilt
Texaco( 2 ) Bakersfield Unocal Los Angeles
Total Refineries in Group 6
Included in complex category due to purchase of shutdown Tosco refinery during 1986
2Group 4 Complex-With CokingFCC( )
Champlin Wilmington Shell Wilmington
Total Refineries in Group 2
2Group 5 Complex-With CokingFCCHCC at 005S Diesel( )
ARCO Carson Chevron El Segundo Mobil Torrance Texaco Wilmington
Subtotal operating 4
Shutdown
Powerine Santa Fe Spr
Total Refineries in Group 5
Group 6 Complex-With CokingFCCHCC at ASTM Diesel
Exxon Benicia Shell Martinez Tosco Martinez Unocal Rodeo amp Santa Maria
Total Refineries in Group 4
1~ Arthur 0 Little Inc B-2
1986 CA Refinery Groups (Continued)
Summary
Operating Shutdown Total
Current ASTM Diesel 23 9 32 Currently at 005S Diesel _ 7_ _1_ _8_
Total __]Q_ _lQ_ ~
(1)( ) Refineries currently producing ASTM diesel (lt 05S)
2 Large refineries in the SCAMD and Ventura Co currently at maximum 005S diesel
11l Arthur D Little Inc B--3
- ----- ~- -__
C REFINERY SURVEY LETTERS
A~ Arthur D Little Inc
AUGUST 14 1987
bullDEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (AOL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE fgtlgtTOR VEHICLE FUELS
THE APPROACH AOL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP fgtlgtDELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY rf)DELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY fgtlgtDELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
YOUR REFINERY AT HAS BEEN SELECTED AS REPRESENTATIVE OF A NLJv1BER OF REFINERIES IN YOUR CONFIGURATION TYPE THE DETAILED DATA REQUESTED IN THE ATTACHED QUESTIONNAIRE WILL ENABLE AOL TO CALIBRATE THEIR fgtlgtDEL FOR REFINERIES OF YOUR CONFIGURATION TYPE FOR 1986 OPERATION
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO AOL BY SEPTEMBER 18 1987 PLEASE ADDRESS YOUR RESPONSE AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK MJ-315 CAMBRIDGE MA 02140
1~ Arthur D Little Inc C-1
AUGUST 14 1987 PAGE 2
MR ROBERT BIMAT JR VICE PRESIDENT REFINING SUNLAND REFINING UlMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS ANO OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HalMES PHD CHIEF RESEARCH DIVISION
1~ Arthur D Little Inc C-2
Refinery Questionnaire I
I Refinery Material Balance and Fuel Use
Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
For all process units provide capacity in MBSD MBCD and 1986 utilization in MBCD In addition please provide the additional process specific data shown below Please provide separate data for multiple process units of the same type where applicable
1 Atmospheric Distillation
TBP cuts on products
2 Vacuum Distillation
TBP cuts on products
3 Catalytic Reforming
typical over point and end point of feed catalyst regeneration (semi-regen cyclic continuous) average quality of feedstock (N + 2A) average severity (RONG) and hydrogen production (MSCFB) maximum severity (RONG) and hydrogen production (MSCFB) operating pressure
4 Isomerization
once through or recycle feedstock
C p1ant c c
5 6purchased natural gasoline
5 Naphtha Hydrotreating
feedstock (SRN Coker Naphtha Hydrocracker Naphtha etc by vol) sulfur in (wt) and sulfur out (wt) hydrogen consumption MSCFB
6 Kerosine Hydrotreating
sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt)
C--3
J1l Arthur D Little Inc
hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
7 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) cetane no in and cetane no out hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
8 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
9 Residual Hydrotreating
feeds tocks sulfur in wt and sulfur out wt aromatics in (vol) and aromatics out (vol) hydrogen consumption MSCFB number of stages maximum sulfur removal and associated H consumption
2operating pressure operating temperature disposition of liquid product
10 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
11 AlkylationPolymerizatiorr-
type (HF Hso4
Cat Poly Dimersol) feedstock (c c
4 c
5 vol)
3
C-4
11l Arthur D Little Inc
12 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
13 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
14 Aromatic Extraction
B T X (vol)
15 Hydrodealkylation
16 MTBE
17 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
18 Solvent Deasphalting
solvent type DAO yield vol DAO quality (Aniline point wtS)
19 Sulfur Recovery
number and capacity of units sulfur recovery (TND) percent sulfur recovery number of units which are redundant but are required by EPA
III Product Blending
1 Gasoline Blending
Please provide the fol~owing data for all gasoline components blended to your 1986 gasoline pool Provide breakdown by gasoline grade if possible
C-5
1~ Arthur 0 Little Inc
COMPONENT 1986 RVP (R+M)2 TOTAL
AROMATICS _liLl 1TOLUENE 1XYLENEC +l
ARO~ATICS MBD psi Clear VOL VOL VOL VOL VOL
LtStraight Run
Natural Gasoline
Nathpha
Re formate
LtHydrocrackate
FCC Gasoline
Alkylate
Cat PolyDimate
BTX
Raffinate
Normal Butane
Iso Butane
Other Refinery
Stocks
Purchased
Toluene
MTBE
Ethanol
Other Purchased
Total Gasoline
(1) Total aromatics and benzene content most important Provide complete aromatics breakdown and test method if available
c--6
11l Arthur D Little Inc
2 Diesel Blending
Please provide the following data for all distillate components blended to your 1986 kerosene jet kerosene diesel and No2 fuel oil pool Show diesel and No2 as one product if not segregated and indicate current degree of segregation possible
COMPONENT 1986
2CETANE
NO SULFUR
1TOTALAROMATICS
1PNA
1NITRATEDPNA
MBD WT VOL VOL Straight Run Kerosene
Straight Run Distillate
FCC LtCycle Oil
Coker Distillate
Hydrocracker Jet
Hydrocracker Distillate
HDT Straight Run Kerosene
HDT Straight Run Distillate
HDT LCO
HDT CGO
Other Refinery stocks
Purchased
Kerosene Stocks
Distillate Stocks
Total Distillate
(1) Total aromatics most important Provide levels of polynuclear aromatics (PNA) nitrated PNA and test method if possible
(2) Provide cetane index if cetane number is not available
c-- 7
1l Arthur D Little Inc
IV Product Specifications
Our analysis will be based on current California Product Specifishycations shown on Table 2 Those specifications that will be controlled in our LP Modelling Analysis are indicated by an asterisk Please indicate any differences in current product specifications (especially gasoline and diesel) for your refinery Our study will analyze the impact of reducing gasoline aromatics levels diesel aromatics levels and diesel sulfur content (except for large refineries in the SCAMD and Ventura County which are currently at 05 wtS)
Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull _Crude slate bull Product slate bull Other feedstocks
Process modifications or additionsbull VI Refinery Operating Costs
Please provide the following refinery operating costs for 1986
000$ $B Crude Variable costs
Catalyst and chemicals Electric power Other variable costs Purchased refinery fuel Subtotal variable costs
Fixed costs 1Contract maintenance
1Maintenance material Maintenance manpower Operations and
1administrative manpower
Tax insurance and other Subtotal fixed costs
Total Cash Costs
(1) Include number of employeescontract laborers by category
C-8
11l Arthur 0 Little Inc
VII Previous Survey Submissions
Under the conditions of secrecy as outlined in our cover letter we would like access to your submissions to the following previous surveys
1 Submission to National Petroleum Council for October 1986 US Petroleum Refining Report
2 Submission to GARB for October 1984 Diesel Fuel Modification Study
3 Submission to GARB for May 1986 Benzene Control Plan
4 Submission to NPRA for 1986 Diesel Fuels Survey
5 DOE Monthly Refinery Reports for 1986 EIA-810
VIII Refinery Contact
Please provide the name of a day-to-day contact for questions regarding your submission
C-9
1~ Arthur 0 Little Inc
-- ---
_ middotbull---clltL bull=-- ~-1
Company location
TABIE 1
1986 Refineu Material Balance
0
I- 0
17 gt r C ~ t -JS -fl
Refinery Irout CXX)BD
1Crude on 1 2 3 4 5 6 Other domestic 7 Other foreign ST Crude Input
IR
N Butane I Butane Natural GasolineNaphtha
2Gasoline Blrdstks
2Distillate Blrdstks Vacuun Gas Oil long Resid Short Resid
3Other Feedstocks Total Input
0 API
X
X
X
X
X
X
X
X
X
X
Sulfur wt
X
X
X
X
X
X
X
6Arcxmtics
vol
X
X
X
X
X
X
X
Benzene vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Cetane no
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
-RVP psi
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
(R-+M)2 clear
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
N+2A vol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
TEL gpgal
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Aniline Pt OF
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Fuel Use
Crude Oil Residual Fuel IR
Natural Gas (MMCF) Still Gas FCC Coke Purchased Elec (Gvlh) Purchased Steam (M) Total (FDEB)
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Please fill in blanks Data not required indicated by x
- - c ~ i__ - I
Company -k
TABIE 1 (Continued) location
1986 Refinery Material Balance f7
I =-Refinery Inout CXXJBD 0 API Sulfur
wt
6Araratics
vol Benzene
vol Cetane
no RVP psi
(R-tM_2 clear
Nt2A vol
TEL gJTIgal
Aniline Pt OF
C I
D Leaded Regular X X X X X
C JS-i )
Leaded Premium Unleaded Regular Unleaded Premium Gasohol
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Total Motor Gasoline X X X X X
Naphtha Jet X X X X X X X X
Kerosine Jet X X X X X X X X
Keros~ X X X X X X X X
Diesel 5No 2 Tuel X
X
X
X
X
X
X
X
X
X
X
X
X
lt1 S Residual X X X X X X X X X
gt1 S Residual X X X X X X X X X
wbricating Oil X X X X X X X X X X
Asphalt Road Oil X X X X X X X X X X
n Wax X X X X X X X X X X I
1-- Petroleum Coke-Marketable X X X X X X X X X X I- Petroleun Coke-Catalyst X X X X X X X X X X
Still Gas 4
Unfinished Oil~ X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Other Products X X X X X X X X X X
Total Output Refinery Gain
Please fill in blanks Data not required indicated by x (1) Identify individual crudes over 10 of slate Balance of crudes in other domestic and other foreign (2) Finished blendstock and unfinished blends tocks by type (3) Identify feedstock type(s) (4) Identify product type (5) Indicate if ccmmn product is produced (6) Indicate test TIEthcxi
~ 1 bullmiddotalte ~
r=
gt r Table_ 2 C p CMJFORNTA PRODUCT SPECIFICATIONS
3I HrNJHllM UNlFAnfD IINLEAOfD JEADED JFADFrgt NAPIITIIA KfROSFNF lOW-SILFIJR IIJGII-SIJlfllR JOJ-SIIIFllll II Ir11-SlllFIIH-middot SlEC1 ~bullJrAfJON llNITS HAXlHIIH IPC RFGUIAR PREf1lUH RFCUIAR PRFHlUH JET JET OJFSFI nrnsr1 Fm1 01 Fll~I Ol IF -- ------- ----
s nond Oct1111eA (R+H) J1Jnfm11m - 175 92 885 92 fl HVI pain 2 Hlnin111m - - - - - 20
H11xfm11m 225 98 9 fl 98 (4) 3098 (4) TEI CmC11l HaxJmum - 0 0 01 01 -llt1t11111bull Vol Haxlm11m 10 ASIgt 01 st 111nt lon I off nt
ISO bullp Hinimtim - 12 12 12 12 Haxinum - 33 33 33 )J
hO bullr Minimum - 15 15 15 15 1-laxfmum - 35 35 35 35
JO bullr Jlfnfmum - 39 39 39 39 l1oximum - 57 57 57 570
I ~10 middotr tllnmum - 49 49 49 49 f-- bullp1111 tllnimum R4 84 84 84N -
Hnxim111n - 95 95 95 95 100 F Hinfmurn - - - - - 60 10
Smoke pt nrm Hlnlmum - - - - - - 20 Spccfflc Gravity Mlnim11m - - - - - o 751 0 775 0R I 6 0816
H11xim11m - - - - - 0802 0840 0876 0f76 0991 2 09Q7 S11l111r wt Mnximum - 003 OOJ 0 15 o 15 040 030 005 o 50 o is en 5l Jo retanc l11ltlrx Mtnfmum - - - - - - - 40 40 l11n1lnometlr flo Minimum - - - - - 44 40 Pour iolnt F H11xfm11m - - - - - - - 0 0 125 Olcfl11sBromine No Equivalent Vol Huxlm11m 5 15 15 15 15 lr11mntrH
Vol H11xfm11m - 25 20
VIAcoHlty nt 122 deg1 Furol Hfnimum - - - - - - - - - 1 5 1 5 Maximum - - - - - - - - - JOO 10(1
Vt11111nl ty nt 11 2 F CcntmiddotI ntokcs Mlnlm11m M11xlm11m - - - - - - - J 5 J5
VIRlt11H1ty tnlex nt ncfutna Hlnfmum - - - - - - - - - 20 21 2021 lgt1 FA Mnxlmnm - - - - - - - - - Jfl I~ JB 125
Fl niltli I 11lex HnxJm11m - - - - - - 705 J71l ) 7f 20fl 20fl
~ Sprc If I rntTn7- i7f Ic1 (1) Southern CA (2) llorthcrn CA (3) Also No 2 Fuel oil (4) Zero lead beyorrl 1988 Specification changes that will be analyzed in our study
AUGUST 141 1987
DEAR MR
SUBJECT SURVEY OF CALIFORNIA REFINERIES HISTORIC OPERATING DATA AND FUTURE PLANS
THE AIR RESOURCES BoARD HAS CONTRACTED WITH ARTHUR D LITTLE INC (ADL) TO ANALVZE THE CoSTS OF REDUCING AROMATICS AND SULFUR LEVELS IN MoTOR VEHICLE FUELS THIS STUDY WILL EXAMINE THE COST IMPACT ON THE CALIFORNIA REFINING INDUSTRY TO REDUCE AROMATICS AND SULFUR LEVELS IN DIESEL AND AROMATICS IN GASOLINE MOTOR VEHICLE FUELS
THE APPROACH ADL WILL TAKE IN DOING THIS ASSIGNMENT IS TO SIMULATE FIVE INDIshyVIDUAL CALIFORNIA REFINERIES USING LP MODELLING THE REFINERIES HAVE BEEN CHOSEN TO REPRESENT CALIFORNIA REFINERY PROCESSING CAPABILITY IN THE REFINING INDUSTRY IN FIVE CONFIGURATION CLASSIFICATIONS THE INDIVIDUAL REFINERY MODELS WILL BE VALIDATED AGAINST ACTUAL REFINERY OPERATION IN TERMS OF CONFIGURATION CAPACITY PROCESSING FLEXIBILITY INPUTS PRODUCT OUTPUTS AND OPERATING COSTS THE RESULTS FROM THE INDIVIDUAL REFINERY MODELS WILL BE SCALED UP FOR EACH OF THE CONFIGURATION GROUPS TO REPRESENT OVERALL CALIFORNIA REFINERY OPERATION IN ORDER TO ENSURE THAT THIS STUDY IS BASED ON THE BEST AVAILABLE INFORMATION AND TO CALIBRATE THE ANALYSIS WE ARE CONDUCTING A SURVEY OF CALIFORNIA REFINERY HISTORIC OPERATING DATA AND FUTURE PLANS
THE DATA REQUESTED ON THE ATTACHED SURVEY FORM WILL ENABLE ADL TO SCALE-UP SELECTED REFINERY DATA FOR REFINERIES IN YOUR CONFIGURATION TYPE TO ASSESS THE OVERALL IMPACT ON THE CALIFORNIA REFINING INDUSTRY IF YOU OPERATE MORE THAN ONE REFINERY IN CALIFORNIA WE REQUEST THAT YOU COMPLETE A SEPARATE SURVEY FOR EACH REFINERY
WE REQUEST THAT THE SURVEY INFORMATION BE FORWARDED TO ADL BY SEPTEMBER 181987 PLEASE ADDRESS YOUR RESPONSES AS FOLLOWS
Ms KATHLEEN M McCARTHY ARTHUR D LITTLE INC ACORN PARK t-o-315 CAMBRIDGE MA 02140
A~ Arthur D Little Inc C-13
AUGUST 14 1987 PAGE 2
MR R P PAVLETIC REFINERY MANAGER CHAMPLIN PETROLELIII CoMPANY
PURSUANT TO THE PROVISIONS OF THE PUBLIC RECORDS ACT (GoVERNMENT CoDE SECTIONS 6250 ET SEQ) AND SECTION 91010 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE THE INFORMATION YOU PROVIDE WILL BE A PUBLIC RECORD AND SUBJECT TO PUBLIC DISCLOshySURE EXCEPT FOR TRADE SECRETS WHICH ARE NOT EMISSION DATA OR OTHER INFORMATION WHICH IS EXEMPT FROM DISCLOSURE OR THE DISCLOSURE OF WHICH IS PROHIBITED BY LAW THE INFORMATION MAY ALSO BE RELEASED TO THE ENVIRONMENTAL PROTECTION AGENCY WHICH PROTECTS TRADE SECRETS AND OTHER CONFIDENTIAL INFORMATION IN ACCORDANCE WITH FEDERAL LAW
INFORMATION CLAIMED TO BE TRADE SECRET OR OTHERWISE EXEMPT FROM DISCLOSURE MAY BE IDENTIFIED AS CONFIDENTIAL IN ACCORDANCE WITH SECTION 91011 TITLE 17 CALIFORNIA ADMINISTRATIVE CoDE WHICH REQUIRES THAT THE CLAIM OF CONFIDENshyTIALITY BE ACCOMPANIED BY AN ADEQUATE JUSTIFICATION THE JUSTIFICATION SHOULD BE AS DETAILED AS POSSIBLE WITHOUT DISCLOSING THE TRADE SECRET OR OTHER CONFIDENTIAL INFORMATION
THE INFORMATION TO BE COLLECTED BY THIS SURVEY IS AN IMPORTANT ELEMENT IN OUR INVESTIGATION OF THE EFFECTS OF CHANGES TO DIESEL FUEL SPECIFICATIONS YOUR PROMPT RESPONSE WILL BE GREATLY APPRECIATED IF YOU HAVE ANY QUESTIONS PLEASE CALL ROBERT GRANT RESEARCH CoNTRACT MANAGER AT (916) 323-5774 TECHNICAL QUESTIONS REGARDING THE SURVEY SHOULD BE MADE TO EITHER KATHLEEN M McCARTHY OR JOHN FELTEN AT (617) 864-5770
THANK YOU FOR YOUR PARTICIPATION
SINCERELY YOURS
JOHN HoLMES PHD CHIEF RESEARCH DIVISION
A~ Arthur D Little Inc C-14
Refinery Questionnaire II
I Please provide the information as indicated on Table 1 attached for the year 1986
II Process Capability
Our analysis will be based on January 1 1987 capacities published in the Oil and Gas Journal and DOE Annual Refinery Surveys unless you provide alternate data
Please provide 1986 process capability for the processes listed below In addition please provide additions to process capability by 1990 based on your current plans under current EPA regulations and ARB regulations
1 Catalytic Reforming
typical over point of feed average quality of feedstock (N + 2A) average severity (RONC) and hydrogen production (MSCFB) maximum severity (RONC) and hydrogen production (MSCFB) operating pressure
2 Distillate Hydrotreating
feedstock (SR Coker FCC LCGO etc) sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
3 Heavy Gas Oil (Vacuum GO) Hydrotreating
feeds tocks sulfur in (wt) and sulfur out (wt) aromatics in (wt) and aromatics out (wt) hydrogen consumption MSCFB number of stages maximum sulfur removal operating pressure
and associated H2
consumption
operating temperature disposition of liquid product
4 FCC
conversion vol yield (olefins gasoline LCCO HCCO) vol feedstock(s) (VGO Coker GO Long resid etc vol) feedstock(s) quality (Aniline point wt S)
A~ Arthur D Little Inc C-15
5 Catalytic Hydrocracking
feedstock(s) (Distillate VGO Coker GO LCO etc vol) hydrogen consumptions (MSCFB) operating pressurepsig number of stages yield (gasoline kerosine distillate vol) maximum severity yield and hydrogen consumption
6 Thermal Processing
type of unit (ie visbreaker delayed coker etc) feedstocks (long resid short resid etc vol)
7 Aromatic Extraction
B T X (vol)
8 Hydrogen GenerationPurification
process type (steam reforming partial oxidation purification) capacity (MSCFB pure H )
2feedstock(s) (still gas natural gas LPG naphtha plant H etc)
2production capability with alternative feedstocks current refinery hydrogen balance surplus (deficit) MMSCFD
III Gasoline Blending
Please provide volume percent blended (R+M)2 clear and volume percent aromatics content of all gasoline components
IV Diesel Blending
Please provide volume percent blended wt sulfur and volume percent aromatics content of all distillate components blended to diesel and No 2 fuel Show diesel and No 2 fuel as one product if not segregated and indicate the degree of segregation possible
V Future Operations
Our analysis will be based on CEC forecasts of crude oil supply and refined product demand for 1990 and 1995
As a guideline for our analysis please provide any planned changes for 1990 and 1995 in your
bull Crude slate bull Product slate bull Other feedstocks bull Process modifications or additions
c--16A~ Arthur D Little Inc
VI Refinery Contact
Please provide the name of contact for questions regarding your submission
Ji~ Arthur D Little Inc C-17
-bull_c
Company TABLE 1 Location
1986 Refinery Material Balance 17 gt-=- 0C Refinery Input 000 BID API Sulfur Aromatics Cetane (R+M) 2 p wt vol no clear t- Crude OilJS-
Alaska X X X-i p California X X X
Other domestic X X X
Foreign X X
Gasoline Blendstocks X X X
Distillate Blendstocks X X
Other Feedstocks X X X X X
Total Input
Refin~ry Output
n I Motor Gasoline X X X
f- 00 Kerosine X X X
Distillate Fuels X
Residualmiddot Fuels X X X X
Other Products X X X X
Total Output
Please fill in blanks Data not required indicated by x
-ltCJ-=-~ middot--
17 I r C 1
C--~~ -
D CHARACTERIZATION OF NEW PROCESS CAPACITY
1
~
STANDARD DISTILLATE HYDROTREATING
o One stage hydrotreating to reduce Sulfur level
ANS Light ANS Heavy Lt Cat Coker2 2
Gas Oil Gas Oil Cycle Oil Gas Oil
Pressure PSIG 650 700 800 800
Catalyst Type CoMo CoMo CoMo CoMo
Feedstock OFTBP Cut 375-500 500-650 375-650 350-600
0 API 372 325 200 292
Wt s 014 057 10 20 Vol Aromatics 224 354 700 400 Cetane Index 408 469 263 334
Consumption SCFB 140 225 700 490H2
Product Quality0 API 377 330 220 31 2
Wt s 0002 003 015 030 Vol Aromatics 213 31 9 560 320 Cetane Index 41 8 479 287 367
Or1erating Cost Consum2tions Fuel FOEBB 0006 0006 0008 0008 Electricity KwhB 1 3 1 3 1 5 15 Steam MB 0012 0012 001 001 Cooling Water MGalB 032 032 048 048 Catalyst amp Chem $B 00063 00063 00068 00068 Manpower MenShift 24 24 25 25
1Ca2ital Related Costs Unit Size MBD 30 30 10 10 Scale Factor e 07 07 07 07 ISBL Cost MM$ 182 182 110 110 Offsites Cost MM$ 91 91 55 55 Maintenance ISBL 40 40 40 40
Offsites 25 25 25 25
1 1987 USGC location California= 105 x USGC location2 Typical data Feedstock quality product quality and hydrogen consumption are feed specific
A~ Arthur D Little Inc D-1
DISTILLATE HYDROREFINING
o Severe hydroprocessing to meet 005 Sulfur
Pressure PSIG
Catalyst Type
Feedstock TBP Cut degF 0
API Wt S Vol Aromatics Cetane Index
H Consumption2
SCFB
Product Quality0
API Wt S Nitrogen ppm Vol Aromatics Cetane Index
Operating Cost Consumptions Fuel FOEBB Electricity KwhB Steam MB Cooling Water MGalB Catalyst amp Chem $B Manpower MenShift
1Capital Related Costs Unit Size MBD Scale Factor e ISBL Cost MM$ Offsites Cost MM$ Maintenance Process
Offsites
1
ANS Heavy Gas Oil
Lt Cat 2
Cycle Oil Coker
2Gas Oil
900 1500 1500
CoMo CoMo CoMo
500-650 375-650 350-600 325 200 292 062 1 0 20
354 700 400 469 263 334
290 950 630
338 254 323 003 005 005
lt10 lt10 lt10 301 490 280 489 330 385
0007 0009 0009 1 3 15 15 0012 001 001 032 048 048 00073 00095 00095 25 25 25
30 10 10 07 07 07
31 8 154 154 159 78 78 40 40 40 25 25 25
1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
1~ Arthur D Little Inc D-2
2
4DISTILLATE AROMATICS REMOVAL
o Two stage hydroprocessing to reduce aromatics to 20 Vol
ANS Heavy Gas Oil
Lt Cat 2Cycle Oil
Coker2
Gas Oil
First Stage Pressure PSIG 900 1500 1500 Catalyst Type CoMo CoMo CoMo
Second Stage Pressure PSIG 1000 1000 1000 Catalyst Type Pt Pt Pt
Feedstock TBP Cut degF 500-650 375-650 350-600 0 API 325 200 292 Wt S 057 10 20 Vol Aromatics 354 700 400 Cetane Index 469 263 334
H2
Consumption SCFB 1015 2000 1280
Product Quality0
API 364 330 343 Sulfur ppm
3Nitrogen ppm
20 lt10
50 lt10
50 lt10
Vol Aromatics 100 200 100 Cetane Index 532 441 423
Operating Cost Consumptions Fuel FOEBB 0025 0025 0025 Electricity KwhB 04 04 04 Steam MB 0012 0012 0012 Cooling Water MGalB 029 029 029 Catalyst amp Chem $B 0029 0029 0029 Manpower MenShift 30 30 30 Platinum troy oz 12000 4000 4000
1Capital Related Costs Unit Size MBD 30 10 10 Scale Factor e 065 065 065 ISBL Cost MM$ 530 260 260 Offsites Cost MM$ 265 130 13 0 Maintenance Process 40 40 40
Offsites 25 25 25
~ 1987 USGC location California= 105 x USGC location Typical data Feedstock quality product quality and hydrogen consumption are feed specific
3 Stage 1 product 1 ppm Nitrogen4 Costs are based on the UOP AH Unibon process extrapolated from commercial processing of straight run distillates To provide definitive estimates of LCO UOP would need to conduct a pilot plant program followed by some engineering design and estimating work
1~ Arthur D Little Inc D-3
MOBIL METHANOL TO OLEFINS PROCESS
Basis Sized on produce 11000 BD distillate on MOGD 1987 US Gulf Coast Costs California= 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD _RU_
Methanol 23305 1000 2918 1000
Output
c c Olefins 19643 843 1680 5763 4 Loss (H o + Volume Shift) 3662 --12__]_ 1238 4242
Total 23305 10005 2918 1000
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 00035 00065
Catalyst amp Chemicals $B $TN 037 429
Cooling Water MGalB MGalTN 100 11 61
Electricity KwhB KwhTN 420 492
Steam MB MTN (credit) (0043) (0500)
Makeup Water MGalB MGalTN 0005 0060
Manpower Shift Pos 30 30
SPB SPTN 000015 00018 1Maintenance $B $TN 0290 3390
2Investment 000 $ 53700 53700
$BD $TND 2734 31964
1 Based on 4 process 25 offsites 330 SDyr2 Includes 50 offsites
A~ Arthur D Little Inc D-4
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PROCESSl
Basis 11000 BD hydrotreated distillate 1987 US Gulf Coast Costs California 105 x USGC location 330 SDyr operation
Volume Basis Weight Basis
Input BSD Vol MTSD ___J_t_L
C3C4 Olefins (4654) 19643 1000 1680 1000 2Hydrogen MSCF MT 4933 12 0 71
Output
LPG 1805 92 146 87
Gasoline 1428 73 168 100
Jet Fuel 3402 173 418 249
Diesel 7 560 2Ll --2fil)_ -2L1
Total 14195 723 1692 1007
Operating Costs $B or $Tn Olefins
Fuel FOE BB FOE TNTN 0 0133 00246
Catalyst amp Chemicals $B $TN 037 433
Cooling Water MGalB MGalTN 0205 243
Electricity KwhB KwhTN 59 691
Steam MB MTN 0118 1 375
Makeup Water MGalB MGalTN 0015 0165
Manpower Shift Pos 30 30
SPB SPTN 0000153 000179 3
Maintenance $B $TN 0265 310
Investment4 000 $ 49050 49050
$BD $TND 2497 29196
1 Including distillate hydrotreater2 Based on 450 SCFB distillate3 Based on 4 process 25 offsites 330 SDyr4 Includes 50 offsites
JI~ Arthur D Little Inc D-5
MOBIL OLEFINS TO GASOLINE AND DISTILLATE PRODUCT QUALITIES
MOGD MTG
Gasoline HDT Jet HDT Diesel Gasoline
Specific Gravity0 API RON Cl RON +3 MON Cl MON +3 FON Cl FON +3 RVP Psig
074 597 92 99 79 86 90 97 11
0 774 384
080 454
074 597 93
100 83 91 87 95
70 100
oC oc
28 51
Parafins Wt Olefins Wt Naphthenes Wt
4 94
0
60 8 0
Aromatics Wt - Benzene Wt - PNA Wt
2 0
4
0
29
0
32
Durene Wt 0 1 8
Sulfur Wt 0 0002 0002 0
50 oc 230 266
1Cetane No Cetane Index
54 68
52 659
ocCloud ocFreeze -60
-55
Viscosity cs 40 cs 50 RI 50
oc oc oc
20 1 3 664
25 1 7 97
1 Use Cetane No
A~ Arthur D Little Inc D-6
~ P gt ~ =ishyi I
D C JS -p
t --J
ASSUMPTIONS FOR 1991 LP MODEL ANALYSIS
PROCESS INVESTMENT COSTS BASE CAPACITY
PROCESS UNIT MBD (FEED)
GASOLINE ALKYLATION 10 CATALYTIC POLYMERIZATION 10 DIMERSOL 10 ONCE THROUGH ISOMERIZATION 5 RECYCLE ISOMERIZATION 5 MTBE 175 ETHEROL 11 C4 ISOMERIZATION 5 REFORMATE EXTRACTION 135 LIGHT FCC GASOLINE EXTRAC 10 FCC GASOLINE FRACTIONATION 20 FCC HEART CUT REFORMING 10 REFORMER 20 FCC GASOLINE HYDROTREATER 20
COMMON PROCESS NAPHTHA HYDROTREATER 20 HYDROGEN PLANT (MMSCFD) 50
DIESEL DISTILLATE HYDROTREATER 30 DISTILLATE HYDROREFINER 10 DEAROMITIZATION(Z) 10 METHANOL TO OLEFINS 196 MOBIL OLEFINS TO DISTILLATE 196
PER BARREL OF PRODUCT PER BARREL OF OLEFIN (1) 1987 USGC basis including 50 offsites (2) Second Stage only
EXPONENT
070 066 066 056 056 060 060 056 065 065 066 070 070 063
063 070
0 70 070 065 065 065
TOTAL INVESTMENT (l) MILLION$
474 21 7 359 77
137 72
113 87
529 215 171 159 529 165
165 482
272 232 164 563 514
Cl H i 0 Cl w
~I ii
i w
i Cl w H 0
--l
deg deg--l
w
JI~ Arthur D Little Inc
~ 17 gt ~ =I
p C-s~ p
1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel without Investment
DIESEL REF 1NERY COST CHANGES
DESCRIPTION frac34 AROMATICS
REDUCT ION PROO
000 BD
2 SULFUR
IITX
2 CE TAME
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOLX
NET FEED ST
000 $0
VAR COST
000 S0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case without Investment 00 291 7 027 437 8 1 307 00 00 00 00 00 00 00 000
25 Sul fur 291 7 017 446 73 299 656 107 228 00 991 08 00 276
M I
I-
20 Sul fur
Hax Sul fur Reduct ion
5X Aromatics Reduction 60
291 7
291 7
291 7
o 15
014
022
447
444
444
70
69
65
292
292
287
4416
5527
611 1
134
175
352
337
41 5
69 7
00
00
00
4887
611 7
7161
40
5 0
58
00
00
00
1677
1991
2080
10 Aromatics Reduction 120 1214 028 440 50 253 6018 482 736 00 723 7 142 00 2576
Hax Aromatics Reduction 8 7 2917 020 444 60 279 15635 640 1236 00 17511 143 00 6030
DESCRIPTION NAPHT
HOT
PROCESS
DI ST 0 I ST HOT HR
ADDITIONS
ARa-1 H2 HOA PLANT
000 B0
MOBIL MOBIL OLEFINS HDGO
PURCHASED STOCKS
SO LA GAS OIL 000 80
Base- Case without Investment 00 00 00 00 oo 00 00 00
25 Sul fur 00 00 00 oo 00 00 00 00
20 Sul fur 00 00 00 00 00 00 00 00
Hax Sul fur Reduct i ~n 00 00 00 00 00 00 00 00
5X Aromatics Reduction 00 00 00 00 00 00 00 00
1OX Aromatics Reduction 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 00 00 00 00 00 00 00 00
1) X Reduction from Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
cmiddot
f7 gt ~ g-t
~ C-F-i fl 1991 Diesel Aromatics amp Sulfur Results - SIJlfMry Diesel with Investment
trj
N
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sul fur
20X Aromatics
15X Arooiat i cs
10 Aromatics
10 Arooiatics at 05 Sul fur
10 Arcmatics with Purch Feedstock
DESCRIPTION
Base Case with Investment
bull 15 Sul fur
05 Sulfur
20 Arcmat i cs
15frac34 Arooiatics
10 Arooiat i cs
10 Arcmat ics at 05 Sul fur
10 Arcma ti cs 1i th Purch Feeds tock
X AROMATICS REDUCTION
o_o
254
516
65 1
651
651
NAPHT HOT
18
00
00
35
5 2
85
85
40
2 PROO
000 8D
291 7
2917
2917
291 7
291 7
291 7
2917
291 7
PROCESS
DIST DIST HOT HR
00 00
71 272
339 785
00 51 5
00 109 7
00 153 5
00 150 7
aa 1296
DIESEL
2 SULFUR CETANE
IITX NO
027 437
011 425
005 449
014 491
007 499
003 509
003 509
003 514
ADDITIONS
AROM H2 HOA PLANT
07 00
00 00
00 00
105 7 00
1790 363
2176 1050
2148 1050
2079 496
REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL AROH AROH FEEDST COST COST COST COST VOLX VOLX 000 SD 000 SD 000 S0 000 $D 000 $D
81 307 00 00 aa aa aa
72 296 1127 144 316 637 2273
68 294 4936 239 567 1898 7660
36 200 646 291 596 2930 4666
16 140 1951 760 1312 6172 10194
03 100 18854 1767 2979 10222 33822
03 100 18761 1948 3142 10379 34231
0 7 100 8104 909 1131 7863 18007
000 80 PURCHASED STOCKS
SO LA MOBIL MOBIL GAS OIL
OLEFINS HOGO 000 BID
00 oo 00
00 00 aa
00 00 00
18 18 00
165 165 aa
55 1 55 l 00
593 593 00
29 7 297 481
TOTAL COST INVEST
CPG bullbull HI LLION S
00 ao
1 9 962
63 2657
38 4102
83 8640
276 14311
279 14531
147 11008
ENERGY 000 80
000
462
196
229
5 20
71 79
10253
3540
1) Reduction frcm Base Case Aromatics Level 2) Includes Refineries Currently at 05 Sulfur
__--~ lj-~ t-~~-
~ 17 gtir C ~ C--Jr I-lt
~ 1991 Diesel Aromatics amp Sulfur Results middot Surmary Diesel Segregation
DIESEL REF I NERY COST CHANGES
OESCRIPT ION AROMATICS
REDUCTION PROO
ODO 8D
2 2 SULFUR
IT CETAHE
HO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
HPRA Segregation bull 05 Sul fur 2917 012 433 81 305 4710 132 441 1246 6528 53 1744 1803
HPRA Segregation 10 Aromatics 307 2917 0132 492 40 211 16365 906 2274 7225 26769 218 10115 61 72
50) Segregation 05 Sul fur 2917 017 434 81 305 130 125 287 925 1467 12 1295 (006)
tcl i
w
so Segregation 10 Aromatics 352 2917
PROCESS
0183 48 7
ADDITIONS
42
ODO
203
8D
1278
PURCHASED STOCKS
514 948 5358 8099 66 7502 292
SO LA NAPHT DIST DIST AROH HZ MOBIL MOBIL GAS OIL
DESCRIPTION HOT HDT HR HOA PLANT OLEF I HS HOGO 000 80
NPRA Segregation 05 Sul fur 00 272 429 oo 00 oo 00 00
HPRA Segregation 10 Aromatics 154 00 893 1221 1050 334 334 00
so Segregation 05 Sul fur 00 00 392 oo 00 oo 00 00
50 Segregation 10 Aromatics 100 00 858 1125 363 159 159 00
1) Reduction from Base Case Aromatics Level 2) Inet udes Refineries Currently at 05 Sul fur
~---iioc _-
~ 17 gtl
2 I
D C F = -ri
irj ~
1991 Costs of Reducing Diesel
Base Case wlnvestment
15 Sulfur
05 Sulfur
20 Aromatics
15 Aromatics
10 Aromatics
10 Aromatics at 05 s
10 Aromatics at 05 S with Purchased Feedstock
SULFUR AROMATICS
wt vol
067 256
015 239
005 233
029 210
0002 137
0002 100
0002 100
002 100
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21-Jul-88
TABLE 1A
Sulfur and Aromatics Levels for Groups I amp II
TOTAL TOTAL CETANE COST COST INVESTMENT
1 MM$yr centsgal MM$
412
203 46 78 13
382 206 347 62
531 31 52 106
487 98 164 309
512 750 1264 514
512 750 1264 514
529 228 384 362
PROCESS CAPACITY
2 000 BD
ENERGY
000 BD
7 4
34 19
18
87
193
(03)
(2)
57
193 57
109 5
~~-~-~-q-
TABLE 1B 17
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups Ill thru VIgt1 g l
p TOTAL TOTALC SULFUR AROMATICS CETANE COST COST INVESTMENT
JS 1 wt vol MM$yr centsgal MM$-i
fl Base Case wlnvestment 021 315 441
15 Sul fur 0 15 296 476 37 10 83
05 Sulfur 005 290 478 74 19 204
20 Aromatics 012 199 485 139 36 304
15 Aromatics 008 140 500 274 71 555
10 Aromatics 0036 100 509 485 125 917
10 Aromatics at 05 s 0035 100 508 500 129 939 trj I 10 Aromatics at 05 S
Ln with Purchased Feedstock 012 100 511 429 11 1 738
1) Based on Groups Ill thru IV Diesel Production of 253000 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
PROCESS CAPACITY ENERGY
2 000 BD 000 BD
27
78
144 3
260 7
347 15
405 46
312 30
21 middotJul middot88
-middotmiddot~--~~
~ 17 gtI g-I
p CJr -p Base Case wInvestment
1991
TABLE 1C
Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California
TOTAL TOTAL SULFUR AROMATl CS CETANE COST COST INVESTMENT
1 wt vol MM$yr centsgal MM$
027 307 437
PROCESS CAPACITY
000 B0 2
ENERGY
000 BD
bull15 Sul fur 0 11 296 425 83 19 96 34 5
05 Sulfur 005 294 449 280 63 266 112 20
20 Aromatics 014 200 491 170 38 410 162 2
15 Aromatics 007 140 499 372 83 864 347 5
10 Aromatics 0032 100 509 1235 276 1431 540 72
trj I
O
10 Aromatics at 05 S
10 Aromatics at 05 S with Purchased Feedstock
0031
0034
100
100
509
514
1249
657
279
147
1453
1101
598
421
103
35
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
21middotJul-88
ecmiddotemicro~=--1 ~_ middot~I
~ 17 gt ~ r C 1
D t F -r
1991
Base Case wInvestment
TABLE 2A
Costs of Reducing Diesel Sulfur and Aromatics Levels for
SULFUR AROMATICS CETANE
wt vol
067 256 412
Groups
TOTAL COST
MM$yr
3 I amp II Hydrogen Plant Sensitivity
TOTAL PROCESS COST INVESTMENT CAPACITY
1 centsgal MM$ 000 BD
2 ENERGY
000 BD
15 Sul fur 015 239 203 46 78 18 9 4
05 Sulfur 005 233 382 211 356 77 41 19
20 Aromatics 029 210 531 36 61 125 27 (03)
15 Aromatics 0002 137 487 98 165 309 87 (2)
10 Aromatics 0002 100 512 749 1262 514 193 57
10 Aromatics at 05 s 0002 100 512 752 1268 514 193 57
tzj
-J 10 Aromatics at 05 S with Purchased Feedstock 002 100 529 228 384 362 109 5
1) Based on Groups I amp II Diesel Production of 38700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21-Jul-88
1---~-
TABLE 2B 3v
1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Groups III thru VI Hydrogen Plant Sensitivitygt s ~ I
D TOTAL TOTAL PROCESSt SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY ENERGY
F-~
1 2 wt vol MM$yr centsgal MM$ 000 BD 000 BD
ri Base Case wlnvestment 021 315 441
15 Sul fur 015 296 476 47 12 113 43
05 Sul fur 005 290 478 92 24 267 126
20 Aromatics 012 199 485 183 47 422 245 3
15 Aromatics 008 140 500 328 85 730 438 7
10 Aromatics 0036 100 509 550 142 1 126 576 15
10 Aromatics at 05 S 0035 100 508 564 145 1146 630 46
10 Aromatics at 05 s trJ with Purchased Feedstock 012 100 511 491 127 937 525 30 I
OJ
1) Based on Groups III thru IV Diesel Production of 253000 B0
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
21- Jul -88
- _=--G_
TABLE 2C 317 1991 Costs of Reducing Diesel Sulfur and Aromatics Levels for Total California Hydrogen Plant Sensitivitygtlr E = TOTAL TOTAL PROCESS C SULFUR AROMATICS CETANE COST COST INVESTMENT CAPACITY F wt vol MM$yr centsgal
1 MM$ 000 BD
2
-r Base Case wlnvestment 027 307 437
15 Sul fur 0 11 296 425 93 21 131 52
05 Sul fur 005 294 449 303 68 344 167
20 Aromatics 014 200 491 219 49 547 272
15 Aromatics 007 140 499 426 95 1039 525
10 Aromatics 0032 100 509 1299 29 1 1640 769
10 Aromatics at 05 S 0031 100 509 1316 284 1660 823 tr1 I 10 Aromatics at 05 S
0 with Purchased Feedstock 0034 100 514 719 16 1 1299 634
1) Based on Groups I thru IV Diesel Production of 291700 BD
2) Includes Hydrogen Plant Capacity in Millions SCFD
3) New Hydrogen Plant Capacity Provided to Support all new Hydroprocessing Investment
ENERGY
000 BD
5
20
2
5
72
103
35
21-Jul-88
--a-bullmiddotpound~
17 gt r C ~ t-F -l 1991 Diesel Aromatics amp Sulfur Results bull Base Case without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT JON PROO
000 BD SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
trj I
I- 0
II 111 V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 019 027 018
396 43 1 414 483 446
6 7 8 7 7 4
103 7 1
224 292 32 5 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
TOTAL CALIFORNIA 00 291 7 027 43 7 81 307 00 00 00 00 00 00 00 000
GROUP DESCRJPT JON
PROCESS
NAPHTHA 0 I ST HDT HDT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 80
MOBIL DLEFINS
PURCHASED STOCKS
SO LA MOBJ L GAS 01 L
MDGD 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 0 0 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 0 0 00 00 00 00
~ 17 gt1r = I= CJS-= fl 1991 Diesel Aromatics amp Sul fur Results middot bull25 Sul fur with out Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROO SULFUR CETANE AROM AROM FEED ST COST COST COST COST COST INVEST ENERGY
GRCXJP DESCRIPTION SULFUR 000 8D IIT NO VOL VOL 000 $0 000 $D 000 $D 000 $D 000 $D CPG MILLION$ 000 BD
I Topping 025 208 025 406 61 213 50 1 16 93 00 610 70 00 205 II Hydrosk i rrmi ng 025 179 023 441 79 27 8 06 03 09 00 18 0 2 00 003 II I + IV Conv + D Conv 025 827 021 443 78 285 40 15 14 00 70 0 2 00 019 V D Conversion LA 025 410 025 498 95 338 98 70 106 00 27 4 16 00 044
trl VJ D Conversion N Cal 025 156 025 46 7 74 279 10 04 05 00 19 03 00 005 i
f- f-
TOTAL TOTAL
HJ GH SULFUR CALIFORNIA
023 019
1780 2917
023 000
453 446
80 73
288 299
656 656
10 7 107
22 8 228
00 00
991 991
13 08
00 0 0
276 276
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM HZ MOBIL MOBIL GAS 01 L
GRCXJP DESCRIPTION HOT HOT HR7 HOA PLANT OLEflNS MOGD 000 8D
I Topping 00 00 00 00 00 00 00 00 II Hydrosk 1 rrmi ng 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Convers 1on LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups Ill V and VI
~--middot
17 gtlr C I
C Jc -l
1991 Diesel Aromatics amp Sulfur Results bull 20 Sulfur without Investment
DIESEL REF JNERY COST CHANGES
GRCIJP OESCRJ PT ION SULFUR PROO
000 80 SULFUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 $D
VAR COST
000 SD
FIXEO COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
trj I
r- N
Topping IJ Hydrosk i rrrn i ng I I I + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL HIGH SUL FUR TOTAL CALIFORNIA
LA N Cal
020 019 021 020 021
021 0 15
208 179 735 410 367
1899 291 7
020 019 021 020 021
021 015
406 44 1 443 498 459
45 4 447
58 76 77 80 7 0
74 70
211 275 283 311 283
281 292
608 61
2592 428 728
4416 4416
9 06 28 74 08
13 4 134
79 19
126 69 4 3
337 33 7
00 00 00 00 00
0 0 00
706 86
274 5 57 0 779
4887 4887
81 1 1 89 33 5 1
6 1 40
00 00 00 00 00
00 00
248 026 962 1 61 280
1677 1677
GRCIJP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS DI L 000 8D
I II I I I V VI
+ IV
Topping Hydrosk irrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 0 0
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups JJ V and VJ
r-bull-imiddotlc- ai1-=-bull -
~ f7 gtlre CJo -r
1991 Diesel Aromatics amp Sulfur Results - Max Sulfur Reduction without Investment
DIESEL REF NERY COST CHANGES
GROUP DESCRIPTION SULFUR PROO
000 BD SULFUR
IIT CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEDST
000 $0
VAR COST
000 $JD
FIXED COST
000 $JD
CAP TAL COST
000 $D
TOTAL COST
000 $JD
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
II I II + IV V VJ
Topping HydroskiITTTiing Conv + D Conv D Conversion - LA D Conversion N Cal
0 10 0 10 021 0 20 0 21
208 17 9 735 410 367
0 10 010 021 020 021
386 420 443 498 459
51 67 77 80 70
20 7 270 283 311 283
1423 356
2592 428 728
52 13 28 74 08
131 46
126 69 4_3
00 00 00 00 00
1606 416
2745 570 779
184 55 89 33 5 1
00 00 00 00 00
585 007 962 161 2 76
t7J I
f- w
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
019 0 14
1899 291 7
019 014
450 444
73 69
280 292
5527 5527
175 175
41 5 41 5
00 00
6117 6117
77 5 0
00 00
1991 1991
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HDT
ADDITIONS
DIST AROM HZ HR7 HDA PLANT
000 80
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITTTii ng Conv + D Conv D Conversion D Conversion
LA N Cal
oo 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups II V and VJ
r~---lt--r
17 gtlr C I
~ C ~~ -P 1991 Diesel Aromatics amp Sulfur Results - 5 Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SUL FUR
IT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $D
VAR COST
000 SD
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST IUVEST
CPG Ml LLION $
ENERGY 000 B0
I II 111 V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv O Conversion 0 Conversion
LA N Cal
100 100 63 40 50
208 17 9
1237 716 577
046 015 019 029 0 15
405 440 424 491 44 7
52 68 53 93 61
202 264 306 315 248
1589 1368 751 43
2360
1 5 13
21 7 82 26
103 85
295 92
123
00 00 00 00 00
1707 1465 1264 216
2508
195 195 24 07
104
00 00 00 00 00
641 5 51
(026) 027 888
rrI I
f- -I-
TOTAL CALIFORNIA 60 291 7 o 22 444 65 287 6111 352 697 00 7161 58 00 2080
GROOP OESCR I PT ION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
01 ST AROM H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
HOGD 000 BID
I II I I I V VI
+ IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 aa 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00
17 gtr C D C ~- -r
1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics Reduction without Investment
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WTX CETANE
NO
POLY AROM VOL
TOTAL AROM VOLX
NET FEEOST
000 $D
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 8D
I II 111 + V VI
IV
Topping Hydrosk i rrrni ng Conv + D Conv D Conversion D middotConversion
LA N Cal
100 100 130
208 179 827
046 015 026
405 440 450
52 68 46
202 264 263
1589 1368 3062
15 13
454
103 85
549
00 00 00
170 7 1465 4065
195 195 11 7
00 00 00
641 551
1384
TOTAL CALIFORNIA 120 1214 028 440 50 253 6018 482 T56 00 723 7 142 00 25 76
[I I
I- J1
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DI ST AROM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 80
I Topping 00 00 00 00 00 00 00 00 II Hydroskirrrning 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv aa 00 00 00 00 00 00 00 V D Conversion LA VI D Conversion N Cal
TOTAL CALIFORNIA 00 0 o 00 00 00 00 00 00
t__-lt------_CCJ )--_Y -
l7 gtr C I
D CJt -P 1991 Diesel Aromatics amp Sulfur Results middot Max Aromatics Reduction without Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCT ION PROO
000 BID SULFUR
WT CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEOST
000 SID
VAR COST
000 $ID
FIXED COST
000 $ID
CAPITAL COST
000 SID
TOTAL COST
000 $ID
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 BID
trj I
f--
deg
I Topping II HydroskilTITling II I + IV Conv + D Conv V D Conversion middot VI D Conversion
TOTAL CALI FORNI A
LA N Cal
140 140 103 60 50
87
208 179
1237 716 577
2917
049 016 019 020 015
020
406 441 422 493 447
444
49 64 52 75 61
60
193 252 304 295 248
279
4995 4299 3364
617 2360
15635
22 19
467 105 26
640
250 207 583 73
123
1236
00 00 00 00 00
00
5268 452 5 4414 796
2508
17511
603 602 85 26
104
143
00 00 00 00 00
00
2013 1733 1142 2 55 888
6030
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA 01ST DI ST AROH H2 MOBIL MOBIL GAS Ol L
GROUP DESCRIPTION HOT HOT HR HOA PLANT OLEFINS MOGD 000 BD
I Topping 00 00 00 00 00 00 00 00 II Hydrosk i ITITli ng 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 00 00
~ 17 gt1 2 1
~ C
~-
-1 1991 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
GRWP DESCR I PT I ON ARc+IAT I CS
REDUCTION PROO
000 BD
DIESEL
SULFUR CETANE WT NO
POLY ARDH VOL
TOTAL AROII VOL
NET FEEDST
000 SD
VAR COST
ODO SD
REF I NERY COST CHANGES
FIXED CAPITAL COST COST
000 SD 000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $
ENERGY 000 BD
MEMO BASE CASE
I NNVESTMENT HILLIDN S
II 111 V VI
+ IV
Topping Hydroskirrming Conv + D Conv D~ Conversion D Conversion
LA N Cal
00 00 00 00 00
208 179
1237 716 577
098 032 018 027 018
396 431 414 483 44 7
67 87 74
103 71
224 292 325 341 260
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
000 000 000 000 000
00 oo 56 00 60
trj I
I-- -J
TOTAL CALIFORNIA 00 2917 027 437 81 30 7 00 00 00 00 00 aa 00 000 116
GRC(JP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DI ST AROM HR HOA
H2 PLANT
000 BID
MOBIL OLEF I NS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS OJ L 000 B0
I II JI I V VI
+ IV
Topping Hydroskirrming Conv + D Conv D Conversion O Conversion
LA N Cal
00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 0 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALI FORNI A 18 00 00 07 00 00 00 00
l7 gtbulltr C l
~ t -J~-lp 1991 l
Diesel Aromatics amp Sul fur Resu ts
bull 15 Sul fur w th Investment
DIESEL REF INERY COST CHANGES
GROOP OESCR l PT l ON SULFUR PROO
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEOST
000 $0
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST
CPG INVEST
MILLION $ ENERGY
000 B0
I II Ill + IV V VI
Topping Hydrosk i nmi ng Conv + D Conv o Conversion o Conversion
LA N Cal
0 15 01 015 015 015
208 179 735 410 367
0 15 014 015 015 015
00 438 473 498 45 7
56 73 77 86 70
209 273 283 325 287
991 13 33 62 28
25 07 12 86 1 5
109 1 7 15
14 7 28
95 00
240 24 7 106
1219 37
299 54 2 176
140 o 5 10 31 1 1
133 00
336 34 5 148
402 007 016 021 016
tr I
I- 0)
TOTAL TOTAL
HIGH SUL FUR CALIFORNIA
015 011
1899 291 7
015 011
420 42 5
75 72
284 296
1127 1127
144 144
316 316
687 68 7
2273 2273
29 19
96 2 96 2
462 462
GROUP OESCR IPT JON NAPHTHA
HOT
PROCESS
DI ST HOT
AOOITIONS
DIST AROH H2 HR7 HOA PLANT
000 B0
MOBIL OLE FI NS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II II I V VI
+ IV
Topping Hydroskinming Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
7 1 00 00 00 00
0 0 00
106 11 2 5 4
00 00 00 00 00
00 00 00 0 0 0 0
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 7 1 27 2 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volume only for Groups III V and VJ
~ 17 gtIr C I
p t
~(S-s f) 1991 Diesel Aromatics amp Sulfur Results bull 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROH AROH FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION X SULFUR 000 B0 IT NO VOL VOL 000 $0 000 S0 000 S0 000 $0 000 $0 CPG deg KILLION S 000 B0
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 505 369 1540 II Hydrosk i rrmi ng 005 179 005 399 64 26 7 938 23 92 178 1231 164 249 358 I II + IV Conv + D Conv 005 735 005 475 76 279 47 1 7 2 1 786 870 28 1100 022 V D Conversion LA 005 410 005 498 77 316 103 98 180 334 714 41 467 039 VI 0 Conversion N Cal 005 367 005 459 63 283 48 10 39 336 433 28 470 016
t1 I
I-
TOTAL TOTAL
HIGH SULFUR CALI FORH IA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
2657 2657
1976 1976
0
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEF INS MOGD 000 BD
I Topping 00 272 oo 00 00 00 00 00 II Hydrosk i rrmi ng 00 67 oo 00 00 00 00 00 111 + IV Conv + D Conv 00 00 386 00 00 00 00 00 V D Conversion LA 00 00 173 00 00 00 00 00 VI D Conversion N Cal 00 00 227 00 00 00 00 00
TOTAL CALI FORNI A 00 339 785 00 00 00 00 00
Note Volune amp CentsGallon are based on High Sulfur Diesel volune only for Groups IJI V and VJ
bull -- -~bullbull7
17 gt ~
2 ~ t-Jtl-= p
1991 Diesel Aromatics amp Sulfur Results bull 20Z Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROATICS PROO SULFUR CETANE ARO ARO FEEDST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 B0 IT NO VOLZ VOLZ 000 $0 000 SD 000 SD 000 $0 000 $0 CPG MILLION S 000 80
I Topping 260 208 042 53 1 4-9 210 (48) 30 72 402 455 52 563 (017)
II Hydrosk i rrm ing 260 179 014 531 49 210 (42) 26 59 358 401 53 501 (014)
111 + JV Conv + D Conv 250 1237 011 489 3 1 20 1 492 72 9 1 1063 1717 33 1488 185
V 0 Conversion middot LA 252 716 014 486 40 189 183 152 324 534 1193 40 747 004
VI D Conversion N Cal 260 57 7 010 476 44 206 263 11 52 573 899 37 802 070
ti N TOTAL CALIFORNIA 254 291 7 014 491 38 200 848 291 598 2930 4666 38 4102 229
0
PROCESS ADDITIONS 000 B0 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST ARO H2 MOBIL MOBIL GAS OIL
GROUP DESCR I PT I OH HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 BD
I Topping 00 00 33 33 00 09 09 oo II Hydroskirrming 00 00 38 38 00 10 10 00 I II + JV Conv + D Conv 00 00 254 495 00 00 00 00 V D Conversion LA 00 00 44 345 00 00 00 00 VI O Conversion N Cal 35 00 146 146 00 00 00 00
TOTAL CALIFORNIA 35 00 515 1057 00 18 18 00
r~---~middotbullo
~ P gt t s 1
I= CJc-~
1991 Diesel Aromatics amp Sulfur Results bull 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GRCAJP DESCRIPTION AROMATICS
REDUCTION PROO
000 BID SULFUR
ITX CETANE
HO
POLY AROH VOL)
TOTAL AROH VOL)
NET FEEDST
000 $D
VAR COST
000 $D
FIXED COST
000 $D
CAP TAL COST
00D $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG Ml LLION S ENERGY
000 8D
I II II I V VI
+ JV
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
520 520 50 1 545 510
208 179
1237 716 57 7
0002 0001 0085 0069 0081
487 487 508 491 495
14 14 12 24 17
137 137 133 15 5 135
(220) (189) 1027 278
1054
152 131 110 178 189
327 27 1 172 405 137
1168 1039 168S 741
1538
1428 125 2 2994 1603 2918
163 166 58 53
120
1636middot 1455 2359 1038 2153
(083) (072) 367 027 281
tr1 I
N c--
TOTAL CALIFORNIA 516 291 7 0069 499 16 140 1951 760 1312 6172 10194 83 8640 520
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OJ L
GRCAJP DESCRIPTION HOT HOT HR7 HDA PLANT OLE FINS MOGD 000 8D
I Topping 00 00 80 74 170 43 43 00 II Hydrosk irrming 00 00 90 83 192 49 49 00 II I + JV Conv + D Conv 00 00 51 7 919 00 00 00 00 V D Conversion LA 00 00 125 433 00 00 00 00 VI D Conversion N Cal 5 2 00 284 281 00 73 73 00
TOTAL CALIFORNIA 5 2 00 1097 1790 363 165 165 00
f7 gtI g- ~ t ~ Jr I f) 1991 Diesel Aromatics amp Sul fur Results bull 10 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
000 SD
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $
ENERGY 000 B0
trJ N N
I Topping 11 Hydrosk ilT1Tli ng II I + IV Conv + O Conv V D Conversion bull VJ D Conversion -
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0003 0001 0049 0000 0053
0032
512 512 519 496 503
509
07 0 7 02 02 04
03
100 100 100 100 100
100
7653 6586 1803 1193 1620
18854
392 337 312 508 218
1767
1040 861 296 629 15 2
2979
194 7 1724 2734 2090 1728
10222
11032 9508 514 4 4420 3718
33822
1263 1265
99 14 7 153
27 6
2726 2413 382 7 2926 2419
14311
3037 2613 683 4 14 433
7179
GROOP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 B0
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGO 000 B0
II II l V VI
+ IV
Topping HydroskilT1Tling Conv + D Conv 0 Conversion D Conversion
LA N Cal
aa aa 00 43 42
00 00 00 00 D0
94 106 593 37 7 365
89 102
1082 542 361
493 558 aa 00 OD
11 4 131 10 5 121 80
114 131 105 121 80
00 aa 00 00 00
TOTAl CALI FORNI A 85 00 153 5 2176 105 0 55 1 551 00
17 gtr C ~ t F -r 1991 Diesel Aromatics amp Sulfur Results bull 10 Aromatics at 05 Sulfur with Investment
DIESEL REF I NERY COST CHANGES
GRCVJP DE SCRIPT ION AROMATICS
REDUCTION PROD
000 80 SULFUR
ID CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEEDST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG Ml LLION $ ENERGY
000 80
I II 111 V VI
+ IV
Topping Hydrosk i ITITli ng Conv + D Conv 0 Conversion bull D Conversion
LA N Cal
650 650 625 707 640
208 17 9
1237 716 57 7
0003 0001 0049 0000 0047
512 512 519 496 500
07 07 02 02 03
100 100 100 100 100
7653 6586 1803 1193 1528
392 337 312 508 399
104 0 861 296 629 316
194 7 1724 2734 2090 1885
11032 9508 5144 4420 4128
1263 1265
99 14 7 170
2726 2413 3827 2926 2639
3037 2613 683 414
3506
trl I
N L0
TOTAL CALJ FORNI A 65 1 2917 0031 509 03 100 18761 1948 3142 10379 34231 279 14531 10253
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HOT HOT
ADDITIONS
D1ST AROM H2 HR7 HOA PLANT
000 80
MOBIL OLEFINS
MOBIL MOGO
PURCHASED STOCKS
SO LA GAS 01 L 000 80
I II 111 V VI
+ IV
Topping HydroskilTITling Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 43 4 2
00 00 00 00 00
94 106 593 377 337
89 102
1082 542 333
493 55 8 00 00 00
114 13 1 105 121 122
114 13 1 105 121 122
00 00 00 00 00
TOTAL CALIFORNIA 85 00 1507 2148 1050 593 593 00
~ f7 gtlr = I
p C-Jil -fl
1991 Diesel Aromatics amp Sul fur Results - 10 Aromatics with Investment amp Purchased Feedstock
DIESEL REF I NERY COST CHANGES
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 B0 SULFUR
WT CETANE
NO
POLY ARCH VOL
TOTAL ARCH VOL
NET FEEDST
000 $0
VAR COST
000 $D
FIXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
tr1 I
1-l -I--
I Topping II Hydroskirrming III + IV Conv + O Conv V D Conversion VI D Conversion
TOTAL CALI FORNI A
LA N Cal
650 650 625 707 640
651
208 179
1237 716 577
2917
0001 0032 0050 0008 0047
0034
529 529 519 497 51 1
514
12 12 04 07 10
07
100 100 100 100 100
100
1385 1192 2137 1474 1916
8104
214 184 186 292 33
909
372 308 235 272 (56)
1131
1376 1212 252 1 1615 1138
7863
3348 2896 5079 3652 3032
18007
383 385 98
12 1 125
147
1927 1697 3530 226 1 1594
11008
283 243
(234) 178
3070
35 40
GROUP DESCRIPTION
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST ARCH H2 HR7 HOA PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBIL GAS OIL
MOGO 000 BD
I II II I V VI
+ IV
Topping Hydroskirrming Conv + D Conv 0 Conversion D Conversion
LA N Cal
00 00 00 40 00
00 00 00 00 00
77 88
593 205 333
70 80
1081 518 330
233 263 00 00 00
65 74 68 75 14
65 74 68 75 14
65 74 83
113 146
TOTAL CALI FORM IA 40 00 1296 2079 496 297 297 481
~ gtI sect p C-J~-~ 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 05 Sulfur with Investment
DIESEL REF INERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL PROD SULFUR CETANE AROM AROM FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION SULFUR 000 8D Ill NO VOL VOL 000 $D 000 $D 000 $D 000 $D 000 $D CPG O MILLION $ 000 80
I Topping 005 208 005 367 49 204 3800 92 255 264 441 1 50 5 369 15 40 II Hydroskirrming 005 179 005 399 64 267 938 23 92 178 123 1 164 249 358 111 + IV V
Conv + 0 Conv D Conversion LA
005 005
62 1 306
005 005
423 463
80 100
294 299
(22) 00
13 00
7 0 00
604 00
664 00
2 5 00
845 00
(074) 000
M VI D Conversion N Cal 005 184 005 469 59 288 (06) 04 2 4 200 221 29 280 (021) I
N TOTAL CALIFORNIA 005 1498 005 426 75 279 4710 132 441 1246 6528 104 1744 1803 V 0 12 2917 012 433 8 1 305 4710 132 441 1246 6528 53 1744 1803
PROCESS ADDITIONS 000 8D PURCHASED STOCKS
SO LA NAPHTHA DIST DIST AROM HZ MOBIL MOBIL GAS 01 L
GROOP DESCRIPTION HDT HDT HR HDA PLANT OLE FINS MOGD 000 BD
Topping 00 27 2 00 00 00 00 00 00 II Hydrosk i rrmi ng 00 00 67 00 00 00 00 00 I II + IV Conv + D Conv 00 00 265 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 00 VI D Conversion N Cal 00 00 97 00 00 00 00 00
TOTAL CALIFORNIA 00 27 2 429 00 00 00 00 00
-bull-
~ 17 gtIr = -i
p CJt-= ri 1991 Diesel Aromatics amp Sulfur Resultsmiddot NPRA Segregation 10X Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROUP DESCR I PT ION X ARa-AT ICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO
POLY ARa-1 VOLX
TOTAL ARa-1 VOL
NET FEEDST
000 SD
VAR COST
000 SD
FIXED COST
000 SD
CAPITAL COST
000 $D
TOTAL COST
000 $D
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 8D
II Ill V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion bull D Conversion
LA N Cal
674 674 674 674 674
208 179 723 306 289
0003 0001 0049 0050 0047
512 512 537 51 1 493
07 07 01 02 03
100 100 100 100 100
7653 6586 919 777 430
392 337 122 36 19
1040 861 15 2 173 4 7
1947 1724 1930 914 71 1
11032 9508 3121 1901 1208
1263 1265 103 148 99
2726 2413 270 1 1279 996
3037 2613 366 099 056
rri I
N 0
TOTAL CALIFORNIA 674 314
170 5 291 7
0038 0132
519 492
03 40
100 21 1
16365 16365
906 906
2274 2274
7225 7225
26769 26769
374 218
10115 10115
61 72 6172
GROUP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HOT
ADDITIONS
DI ST ARa-1 HR7 HOA
HZ PLANT
000 80
MOBIL OLEFINS
MOBIL HOGD
PURCHASED STOCKS
SO LA GAS OIL 000 BD
I II 111 V VI
+ IV
Topping Hydroskimning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00
102 5 2
00 00 00 00 00
94 106 495 00
197
89 102 666 214 149
493 558
00 00 00
114 131 42 48 00
114 131 42 48 00
00 00 00 00 00
TOTAL CALIFORNIA 154 00 893 1221 1050 334 334 00
17 gtI sect = t t F -ri
1991 Diesel Aromatics amp Sulfur Resultsmiddot so Segregation OS Sulfur with Investment
DIESEL REF NERY COST CHANGES
GRCIJP DESCRIPTION X SULFUR PROO
000 8D SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOLX
NET FEED ST
000 $0
VAR COST
000 $0
FIXED COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION S ENERGY
000 B0
I II Ill V VI
+ IV
Topping Hydrosk irrrni ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
005 005 005 005 005
104 90
414 35 8 184
005 005 005 005 005
359 399 423 499 469
so 64 80
123 59
209 267 294 370 288
65 16
(15) 70
(06)
37 09 09 67 04
67 24 54
118 24
00 00
454 271 200
169 49
501 526 221
39 13 29 35 29
00 00
635 380 280
031 007
(049) 027
(021)
tr1 I
N -I
TOTAL CALIFORNIA 005 017
1149 2917
005 017
446 434
86 81
307 305
130 130
125 125
287 287
925 925
1467 1467
30 12
1295 1295
(006) (006)
GRCIJP OESCR IPT ON
PROCESS
NAPHTHA DIST HOT HOT
ADDITIONS
DIST AROH HR7 HOA
H2 PLANT
000 B0
MOBIL OLE FINS
PURCHASED STOCKS
SO LA MOBIL GAS 01 L
MOGD 000 B0
I II Ill V VI
+ IV
Topping Hydrosk i rrrn ng Conv + 0 Conv 0 Conversion D Conversion
LA N Cal
00 00 00 00 00
00 00 00 00 00
00 00
176 119 97
00 00 00 00 OO
00 00 00 00 00
00 00 00 00 00
oo oo 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 00 00 392 00 00 00 00 00
17 gt ~ =shyc p t---JD- p
1991 Diesel Aromatics amp Sulfur Results bull SOX Segregation 10 Aromatics with Investment
DIESEL REFINERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL
GROUP DESCRIPTION AROMATICS
REDUCTION PROO
000 BD SULFUR
IITX CETANE
NO AROH VOL)
ARcraquoI VOLX
FEEDST 000 S0
COST 000 $0
COST 000 S0
COST 000 $0
COST 000 S0
COST INVEST CPG HI LLION S
ENERGY 000 80
I II 111 + IV
Topping Hydroskinming Conv + D Conv
674 674 674
104 90
619
0003 0001 0049
529 511 537
12 05 01
100 100 100
(265) (228) 688
147 127 42
273 226 123
1106 968
1306
1261 1092 2158
289 291 83
1549 1355 1828
(108) (093) 268
tr1
V VI
D Conversion middot LA D Conversion middot N Cal
674 674
358 289
0050 0047
51 1 493
02 03
100 100
654 430
180 19
279 47
1267 711
2380 1208
158 99
1774 996
170 056
N CXl TOTAL CALIFORNIA 674 1459 0043 520 03 100 1278 514 948 5358 8099 132 7502 292
339 2917 0183 487 42 203 1278 514 948 5358 8099 132 7502 292
PROCESS ADDITIONS 000 80 PURCHASED STOCKS
SO LA NAPHTHA DI ST DIST AROH H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS HOGO 000 80
I II
Topping Hydroskinming
00 00
00 00
50 57
49 55
17 1 192
49 55
49 55
00 00
111 + IV Conv + D Conv 00 00 375 625 00 00 00 00 V D Conversion LA 48 00 178 246 00 55 55 00 VI D Conversion N Cal 52 00 197 149 00 00 00 00
TOTAL CALIFORNIA 100 00 858 1125 363 159 159 00
7 gt r = ~ C S- i p
F 1991 DIESEL AND GASOLINE COST EQUATIONS
~~
rj I
I-
f7
gtIr i I
p CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv amp Purch Feed
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
GROUP I COST EQUATION COMPONENTS FOR 1991 $ B
Feedstock Variable Fixed Capital Total
000 000 000 000 000 241 008 045 000 294 292 009 038 000 339 684 025 063 000 772 764 007 050 000 821 764 007 050 000 821
2401 011 120 000 2532
000 000 000 000 000 476 012 052 046 586
1827 044 123 127 2121 (023) (106) 3679
014 073 188
035 157 500
193 562 936
219 686
5303 36 79 188 500 936 5303
666 103 1 79 662 1610
1827 044 123 127 2121 3679 188 500 936 5303 063 036 064 000 163
(255) 141 263 1063 1212
~~---bullj
GROUP II COST EQUATION COMPONENTS FOR 1991 $ B 0
~ 17 gt-i-=-=-i t--Jr-= fl
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt Sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock --- - - - ---
000 003 034 199 764 764
2402
Variable - - -- -- -
000 002 003 007 007 007 0 11
Fixed
000 005 011 026 047 047 116
Capital
000 000 000 000 000 000 000
Total
000 010 048 232 818 818
2529
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sutf 10 Aromatics wInv ampPurch Feed
000 007 524
(023) (106) 3679 3679 666
000 004 013 015 073 188 188 103
000 009 051 033 151 481 481 172
000 000 099 200 580 963 963 677
000 020 687 225 698
5311 53 11 1618
Tj I
N
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
524 3679
018 (253)
013 188 010 141
051 481 027 251
099 963 000
1076
687 5311 055
12 15
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 2464
000 008
000 130
000 000
000 2602
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wlnv Max Aromatics Red wlnv Max Aromatics Red wlnv ampPurch Feed
000 347
347 010
000 020
020 (008)
000 072
072 (042)
000 217
217 001
000 656
656 (039)
~~-~
GROUPS Ill amp IV COST EQUATION COMPONENTS FOR 1991 $ B bullmbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbullbull-bullbullbullbull-bullbullbull-bullbullbullbullbullbull-bullbullbullbullbullbullbullbullbullbullbullbullbullbullbull
~ 17 gt1 =-C 1
D CJS -ri
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - -- --
000 005 353 353 061 370 272
Variable - - --
000 002 004 004 018 055 038
Fixed
000 002 0 17 017 024 066 047
Capital
000 000 000 000 000 000 000
Total
000 009 3 74 374 103 491 357
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv 10 Aromatics wInv at 05 Sulf 10 Aromatics wInv ampPurch Feed
000 004 006 040 083 146 146 1 73
000 001 002 006 009 025 025 015
000 002 003 007 014 024 024 019
000 033 107 086 136 221 221 204
000 040 118 139 242 416 416 4 11
t-zj I
l)
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wlnv NPRA Segregation 10 Aromatics wlnv 50 Segregation 05 Sulfur wlnv 50 Segregation 10 Aromatics wlnv
(004) 127
(004) 111
002 017 002 007
0 11 021 013 020
097 267 110 211
106 432 121 349
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 049
000 006
000 007
000 000
000 062
BC with Investment 5 Aromatics Red wInv 10 Aromatics Red wlnv 15 Aromatics Red wlnv 20 Aromatics Red wInv Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
000 (001) 001 092
092 041
000 (001) 003 022
022 (001)
000 (000) 005 056
056 (001)
000 006 0 11 136
136 021
000 004 020 306
306 060
middot-- micro__
~ GROUP V COST EQUATION COMPONENTS FOR 1991 $ B 17 - -- - -- gt r -c Feedstock Variable Fixed Capital Total ~ --- - -- -- - -t
DIESEL RUNS -p--BC without Investment 000 000 000 000 000 - 25 wt Sulfur wo Inv 024 017 026 000 067ri 20 wt Sulfur wo Inv 104 018 017 000 139 Max Sulfur Red wo Inv 104 018 0 17 000 139 5 Aromatics Red wo Inv 006 011 013 000 030 10 Aromatics Red wo Inv Max Aromatics Red wo Inv 006 0 11 013 000 030
BC with Investment 000 000 000 000 000 15 wt Sulfur wInv 015 021 036 060 1 32 05 wt Sulfur wInv 025 024 044 081 1 74 20 Aromatics wlnv 026 021 045 075 167 15 Aromatics wlnv 039 025 057 103 224 10 Aromatics wlnv 167 0 71 088 292 618 10 Aromatics wInv at 05 Sulf 167 0 71 088 292 618 10 Aromatics wInv ampPurch Feed 206 041 038 226 5 11
DIESEL SEGREGATION RUNS gtzj
~ i
NPRA Segregation 05 Sulfur wInv 000 000 000 000 ooo NPRA Segregation 10 Aromatics wInv 254 012 057 299 622 50 Segregation 05 Sulfur wlnv 020 019 033 076 148 50 Segregation 10 Aromatics wInv 183 050 078 354 665
GASOLINE RUNS
BC without Investment 000 000 000 000 000 Max Aromatics Red wo Inv 075 003 003 000 081
BC with Investment 000 000 000 000 000 5 Aromatics Red wlnv 034 000 (009) 005 030 10 Aromatics Red wlnv 104 003 002 021 130
middot15 Aromatics Red wlnv 085 002 016 034 137 20 Aromatics Red wInv 060 015 057 084 216 Max Aromatics Red wlnv 060 015 057 084 216 Max Aromatics Red wlnv ampPurch Feed 057 (012) (024) 006 027
~=~-bull-ec~ r- ___-
GROUP VI COST EQUATION COMPONENTS FOR 1991 $ B -- -- - ------------ --- ---- --- - ----- -- -- -- -
17 gt1-=-= 1
I= t F-i ()
DIESEL RUNS
BC without Investment 25 wt Sulfur wo Inv 20 wt sulfur wo Inv Max Sulfur Red wo Inv 5 Aromatics Red wo Inv 10 Aromatics Red wo Inv Max Aromatics Red wo Inv
Feedstock - ----- -
000 003 198 198 409
409
Variable - - - - - -
000 001 002 002 005
005
Fixed
000 001 012 012 021
021
Capital
000 000 000 000 000
000
Total
000 005 212 212 435
435
BC with Investment 15 wt Sulfur wlnv 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wlnv 10 Aromatics wlnv at 05 Sulf 10 Aromatics wlnv ampPurch Feed
000 008 013 046 183 281 265 332
000 004 003 002 033 038 069 006
000 008 0 11 009 024 026 055
(010)
000 029 092 099 267 299 327 1 97
000 049 119 156 507 644 7 16 525
gtTj I
V
DIESEL SEGREGATION RUNS
NPRA Segregation 05 Sulfur wInv NPRA Segregation 10 Aromatics wInv 50 Segregation 05 Sulfur wInv 50 Segregation 10 Aromatics wInv
(003) 149
(003) 149
002 007 002 007
013 016 013 016
109 246 109 246
1 21 418 121 418
GASOLINE RUNS
BC without Investment Max Aromatics Red wo Inv
000 036
000 007
000 015
000 000
000 058
BC with Investment 5 Aromatics Red wlnv 10 Aromatics Red wInv 15 Aromatics Red wInv 20 Aromatics Red wInv Max Aromatics Red wlnv Max Aromatics Red wInv ampPurch Feed
000 (002) 014 007 048 048 106
000 001 004 007 025 025 004
000 002 008 016 082 082 008
000 007 022 046 127 127 037
000 008 048 076 282 282 155
~___
~ 17 gt =shy~ c p CJ0-i p
G 1991 GASOLINE RESULTS
~ r
gt ~ g- I= t F- ri
1991 Gasoline Aromatics amp Benzene Results bull Surmary Gasoline without Investment
MOTOR GASOLI HE REF I NERY COST CHANGES
NET VAR FIXEO CAPITAL TOTAL X AR()IATICS PROO ARC) BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY
OESCR I PT ION REDUCT ION 000 80 VOLX VOLX 000 SD 000 SD 000 SD 000 SD 000 $D COST CPG Kl LL ON $ 000 BD
Base Case without Investment 00 8248 332 197 00 00 00 00 00 00 00 000
Hax Aromatics Reduction 34 8248 321 189 9276 445 885 00 10606 31 00 3110
0 I
I-
PROCESS ADDITITIONS 0 0 0 8 0 PURCHASED FEEDSTOCK$ 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCR I PT I OH HOT HOT PLANT ALKYL POLY DIKERSOL ISa-t SOK MTBE ETHEROL I Sa-I EXTRACT EXTRACT FRAC REFORM 000 BD HTBE ETOH IS() ALKYL TOTAL
Base Case without Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
Hax Aromatics Reduction 0 0 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~J_-j
~ 17 gtir = ~ C--ji -p
0 I
N
1991 Gasoline Aromatics amp Benzene Results middot Sunnary Gasoline with Investment
HOT OR GASOLINE
X AR~ATICS PROO AR~ DESCRIPTION REDUCT ION 000 80 VOLX
Base Case with Investment 00 8248 315
5X Aromatics Reduction 5 1 8248 298
1OX Aromatics Reduction 100 804 5 282
15X Aromatics Reduction 149 8045 267
20 Aromatics Reduction 204 4892 25 5
Max Aromatics Reduction 181 8248 258
Hax Arom Red with Purch Feedstock 187 8248 256
SENZ VOLX
180
1 75
187
162
166
154
152
NET FEEDST
000 SD
00
1640
3647
5730
2993
6529
5577
REF I NERY COST CHANGES
VAR FIXED CAPITAL COST COST COST
000 SD 000 $D 000 $D
00 00 00
4 5 (10 7) 919
287 399 1697
940 2615 middot 640S
1076 3710 557 7
182 1 5608 10251
(329) (66SJ 1690
TOTAL COST
000 $D
00
2497
6031
15690
13355
24209
6273
TOTAL INVEST COST CPG MILLION S
00 00
07 1286
18 237 6
46 8968
65 7808
70 14351
18 236 7
ENERGY 000 8D
000
340
7 70
2460
1900
3720
(1400)
PROCESS ADDITITION~ 0 0 0 B D PURCHASED FEEDSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ~LKYL POLY OIHERSOL IS~ IS~ HTBE ETHEROL IS~ EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH IS~ ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
5 Aromatics Reduction 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 o 1 00 00 00 00 00
10) Aromatics Reduction 4 0 00 00 00 00 03 00 478 146 62 331 40 37 401 00 11 00 00 oo oo 00
15frac34 Aromatics Reduction 4 3 0 0 989 00 00 06 00 51 9 18 1 130 925 119 778 767 393 14 I 00 00 oo 00 00
20 Aromatics Reduction 59 00 00 32 00 00 0 0 340 165 70 473 339 985 1364 213 178 00 00 oo 00 00
llax Aromatics Reduction 59 00 1087 3 2 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 oo 00 00
Max Arom Red with Purch Feedstock 2 7 0 0 00 00 0 0 0 3 00 490 171 134 82 14 5 19 130 0 0 61 306 0 0 0 o 2 1 32 7
1) Reduction from Base Case Aromatics Level
~ I gt ~ =shy=I
I= C F fl 1991 Gasoline Aromatics amp Benzene Results - Base Case without Investment
MOTOR GASOLINE REFINERY COST CHANGES
----NET VAR FIXED CAPITAL TOTAL
AROMATICS PROO AROH BENZ FEED ST COST COST COST COST TOTAL INVEST ENERGY GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 S0 000 S0 000 S0 000 $0 COST CPG HI LLION S 000 B0
0 J I Topping 00 18 374 266 00 00 00 00 00 - 00 00 00
w II Ill + JV
Hydrosk irrmi ng Conv + 0 Conv
00 00
185 3153
458 318
326 181
00 00
00 00
00 00
00 00
00 00
00 00
00 00
00 00
V D Conversion LA 00 2585 320 196 00 00 00 00 00 00 00 00 VJ D Conversion N Cal 00 230 7 356 209 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 8248 332 197 00 00 00 00 00 00 0 0 00
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLAHT ALKYL POLY DIMERSOL ISOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D HISE ETOH ISOM ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 111 + IV Conv + 0 Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r _ -_
17 gti a p t--~--= p
1991 Gasoline Aromatics amp Benzene Resultsmiddot Hax Aromatics Reduction without Investment
MOTOR GASOLINE REFINERY COST CHANGES
0 I
i--
GRCIJP
I II 111 + V VI
IV
DESCRIPTION
Topping Hydroskirrming Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCTION
00 10 46 42 11
PROO 000 B0
18 185
3153 2585 2307
AROM VOL
374 middot 455 302 306 352
BENZ VOL
266 251 172 200 196
NET FEEDST
000 S0
00 4558 1533 235 1 834
VAR COST
000 $0
00 15
180 82
167
FIXED COST
000 S0
00 240 215 89
340
CAPITAL COST
000 $0
00 00 00 00 00
TOTAL COST
000 $0
00 4814 1930 2523 1341
TOTAL INVEST COST CPG MILLION $
00 00 620 00 5 00 23 00 14 00
ENERGY 000 B0
00 183 34 78 16
TOTAL CALI FORNI A 34 8248 32 1 189 9276 445 885 00 10606 31 00 311
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE REFORM- FCC FCC BTX NAPHTHA GASD H2 CAT THRU RECYCLE C4 ATE GASD GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY OJHERSOL ISOM ISOM MTBE ETHERDL I SOM EXTRACT EXTRACT FRAC RE FORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
J Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II I + IV Conv + D Conv 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNIA 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00
i) Reduction from Base Case Aromatics Level
= ~=--r
17 gt ~ r = I t i JP-B
1991 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
G I
V
GROUP
Imiddot II I II + V VI
IV
DESCRIPTION
Topping Hydrosk i nrni ng Conv + D Conv D Conversion D Conversion
LA N Cal
AROMATICS REDUCT ION
00 00 00 oo 00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
18 374 266 185 36 1 261
3153 302 176 2565 295 169 2307 349 189
NET FEEDST
000 S0
oo 00 oo 00 00
VAR COST
000 S0
00 00 oo 00 oo
FIXED COST
000 SD
00 00 00 oo oo
REF I NERY COST CHANGES
CAPITAL TOTAL COST COST TOTAL INVEST
000 S0 000 SD COST CPG MILLION S
00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 oo 00 00 00
ENERGY 000 B0
00 00 00 00 00
MEMO BASE CASE
INVEST MILLION $
00 202 613 622 56 1
TOTAL CALIFORNIA 00 8248 315 180 00 oo oo 00 00 00 00 00 1998
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI MERSOL ISOM ISOM HTBE ET HEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 BD MTBE ETOH ISOM ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydrosk i nrni ng 00 00 00 00 00 00 00 35 00 00 00 00 00 00 00 00 00 oo 00 00 00 III + IV Conv + D Conv 00 00 00 00 00 00 00 51 33 62 02 02 00 00 00 00 00 oo 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 214 00 00 10 00 00 00 00 00 00 oo 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 00 00 92 46 00 00 00 00 00 00 00 00 oo 00 00
TOTAL CALI FORNI A 49 00 00 00 00 00 00 300 125 108 12 02 00 00 00 00 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~_-__J ~--- ___J -7
~ 17 gt t =shyc ~ CJo-= ri
1991 Gasoline Aromatics amp Benzene Results bull 5 Aromatics Reduction with Investment
MOTOR GASOLINE REF NERY COST CHANGES
NET VAR FIXED CAP TAL TOTAL X AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
0 GROOP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION $ 000 B0 I
(J I Topping 00 18 374 266 00 00 00 00 00 00 00 middot 00 II Hydrosk irrmi ng 50 185 343 330 642 37 138 40 1 1218 15 7 561 20 111 + IV Conv + D Conv 54 3153 286 158 (35) (26) (05) 195 129 01 273 (02) V D Conversion LA 50 2585 280 184 1067 10 (283) 169 963 09 236 30 VI D Conversion N Cal 50 2307 331 1 75 (35) 24 43 155 187 02 21 7 (01)
TOTAL CALIFORNIA 5 1 8248 298 175 1640 4 5 (107) 919 249 7 07 1286 34
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 B0 MTBE ETOH SOH ALKYL TOTAL
I Topping 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 II Hydroskirrming 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 00 00 I II + JV Conv + D Conv 00 00 00 00 00 00 42 72 58 62 02 02 00 00 00 01 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 221 00 00 149 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 49 00 00 00 00 00 54 30 92 00 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALIFORNJA 49 00 99 00 00 00 96 362 150 62 203 12 00 00 00 01 00 00 00 00 00
1) Reduction from Base case Aromatics Level
i=ao~--__
17 gt ~ r = ~ C it- r 1991 Gasoline Aromatics amp Benzene Results bull 10) Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPJ TAL TOTAL AR(ltATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROUP DESCRIPTION REDUCTION 000 BD VOLfrac34 VOL 000 $0 000 S0 000 S0 000 $D 000 $D COST CPG HI LLION S 000 BD
I Topping II Hydroskirrming
G) Ill + IV Conv + D Conv 99 3153 272 152 26 96 143 351 815 06 770 (01)
---J V VI
D Conversion D Conversion
LA N Cal
100 100
2585 230 7
266 314
219 197
3289 332
95 97
66 190
648 499
4098 1118
38 1 2
907 699
63 15
TOTAL CALI FORNI A 100 8045 282 187 3647 287 399 1697 6031 18 2376 77
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 B0
FCC ONCE REFORMmiddot FCC FCC STX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HDT HDT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH IS(lt ALKYL TOTAL
I Topping II Hydroskirrming Ill + JV Conv + D Conv 00 00 00 00 00 03 oo 165 54 62 35 40 00 00 00 1 1 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 oo 221 00 00 197 00 37 231 00 00 00 00 00 00 00 VI 0 Conversion N Cal 40 00 00 00 00 00 00 92 92 00 100 00 00 170 00 00 00 00 00 00 00
TOTAL CALIFORNIA 40 00 00 00 00 03 00 478 146 62 331 40 37 401 00 1 1 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
~ 17 gt ~ =shy= I
~ t js- p 1991 Gasoline Aromatics amp Benzene Results bull 15 Aromatics Reduction with Investment
MOTOR GASOLINE REF I NERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL ARcraquoIATICS PROO ARcraquoI BENZ FEEOST COST COST COST COST TOTAL INVEST ENERGY
GRCXJP DESCRIPTION REDUCTION 000 BD VOL VOL 000 $0 000 $D 000 $0 000 $D 000 SD COST CPG MILLION $ 000 BD
I Topping 0 II HydroskilTITiing I 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162
co V D Conversion LA 150 2585 251 204 2685 6 7 494 1077 4322 40 1508 55 VI D Conversion N Cal 150 2307 296 166 15 1 165 361 1055 1731 18 1477 29
TOTAL CALIFORNIA 149 8045 267 162 5730 940 2615 6405 15690 46 8968 246
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEED STOCKS 000 BD
FCC ONCE RE FORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRCXJP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM SOM MTBE ET HEROL I SOM EX TRACT EXTRACT FRAC RE FORM 000 80 MTBE ETOH ISOM ALKYL TOTAL
l Topping II Hydroskirnning 111 + IV Conv + D Conv 00 00 989 00 00 06 00 206 5 7 65 588 8 7 524 416 388 101 00 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 219 30 65 199 00 24 1 132 00 00 00 00 00 00 00 VI O Conversion N Cal 43 00 00 00 00 00 00 94 94 00 138 62 13 219 05 42 00 00 00 00 00
TOTAL CALIFORNIA 43 00 989 00 00 06 00 519 181 130 925 149 778 767 393 144 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
r-middot-~-
17 gt ~ r C ~ t ~
JDdeg-I l 1991 Gasoline Aromatics amp Benzene Resultsmiddot 20 Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
GROUP DESCRIPTION X AROMATICS
REDUCTION PROO
000 B0 ARCH VOL
BENZ VOLX
NET FEEOST
000 S0
VAR COST
000 S0
FIXED COST
000 S0
CAPITAL COST
000 $0
TOTAL COST
000 $0 TOTAL
COST CPG INVEST
MILLION $ ENERGY
000 BD
0
-
l II Ill + IV
V VI
Topping Hydroskirrrning Conv + D Conv D Conversion 0 Conversion
LA N Cal
200 208
2585 230 7
236 276
182 149
1878 1114
488 588
1810 1900
2654 2923
6830 6525
63 67
3716 4092
100 90
TOTAL CALI FORNI A 204 4892 255 166 2993 1076 3710 557 7 13355 65 7808 190
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEDSTOCKS 000 8D
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DIHERSOL ISOM ISOM HTBE ETHEROL I SOH EXTRACT EXTRACT FRAC REFORM 000 8D HTBE ETOH ISOM ALKYL TOTAL
Topping II Hydroskirrrning 111 + IV Conv + D Conv V o Conversion LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI D Conversion N Cal 59 00 00 32 00 00 00 113 100 00 264 67 480 90 1 213 178 00 00 00 00 00
TOTAL CALIFORNIA 59 00 00 32 00 00 00 34 0 165 70 473 339 985 1364 213 178 00 00 00 00 00
1 l Reduction from Base Case Aromatics Level
~--JF _-c~~-1 -
17 gtl g-I
p t aJtl -p 1991 Gasoline Aromatics amp Benzene Resultsmiddot Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL AROMATICS PROO AROH BENZ FEEDST COST COST COST COST TOTAL INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 80 VOL VOL 000 $0 000 $0 000 S0 000 $0 000 $0 COST CPG MILLION S 000 80
0 I Topping 00 18 37 4 266 00 00 oo 00 oo oo 00 00 I II Hydroskirrrning 50 185 343 330 642 37 138 401 1218 15 7 561 20
I- 111 + IV Conv + D Conv 148 3153 258 124 2894 709 1760 4274 9636 73 5983 162 0 V o Conversion LA 200 2585 236 182 1878 488 1810 2654 6830 63 3716 100
VI D Conversion N Cal 208 2307 276 149 1114 588 1900 2923 6525 67 4092 90
TOTAL CALIFORNIA 181 8248 258 154 6529 1821 5608 10251 24209 70 14351 372
PROCESS ADDITIONS 0 0 0 B D PURCHASED FEEOSTOCKS 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY O I MERSOL ISOM ISOH HTBE ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 80 HTBE ETOH ISOH ALKYL TOTAL
Topping 00 00 00 00 00 00 00 00 00 00 00 00 oo 00 00 00 00 00 00 00 00 II Hydrosk irrrning 00 00 99 00 00 00 00 39 00 00 52 10 00 00 00 00 00 00 00 oo 00 111 + IV Conv + o Conv 00 00 988 00 00 06 00 206 57 65 588 87 524 416 388 101 00 00 00 00 00 V D Conversion middot LA 00 00 00 00 00 00 00 226 65 70 209 271 505 463 00 00 00 00 00 00 00 VI O Conversion N Cal 59 00 00 3 2 00 00 00 113 100 00 264 6 7 480 901 213 178 00 00 00 oo oo
TOTAL CALIFORNIA 59 00 1087 32 00 06 00 584 222 135 1113 436 1509 1780 601 280 00 00 00 00 00
1) Reduction from Base Case Aromatics Level
c_-o_-NI
17 gt t r C I
p t--~ -s
1991 Gasoline Aromatics amp Benzene Results middot Hax Aromatics Reduction with Investment amp Purchased Feedstock
MOTOR GASOLINE REF I NERY COST CHANGES
GROUP OESCR I PT I ON X AROHAT JCS
REDUCT ION PROO
000 B0 AROH VOLX
BENZ VDLX
NET FEEOST
000 $0
VAR COST
000 S0
f IXEO COST
000 $0
CAPITAL COST
000 $D
TOTAL COST
000 SD TOTAL INVEST
COST CPG MILLION S ENERGY
000 B0
0 I ~ ~
Topping II Hydroskinming 111 + JV Conv + D Conv V 0 Conversion VI D Conv~rsion
TOTAL CALIFORNIA
LA N C~l
00 290 148 200 208
187
18 185
3153 2585 2307
824 8
371 256 258 236 27 6
256
266 2 21 143 151 1 57
152
00 18
1301 181 1 2447
~577
00 (11) (39)
(371) 91
(329)
00 (78) (2 1)
(759) 193
(665)
00 02
661 174 853
1690
aa (72)
190 2 856
3588
627 3
00 (09) 32 08 3 7
1 8
aa 03
925 21 4
1195
2367
00 ( 16) (31) (85) (08)
( 140)
PROCESS ADDITIONS 0 0 0 B 0 PURCHASED f[EDSIOCKS OllO B0
GROUP DESCRIPTION NAPHTHA
HD
FCC CASO
HOT HZ
PLANT ALKYL CAT
rm y DI MfRSOL
ONCE I HRU R[CYCL[ I Sl1-1 ISOH HTOL l TH[ROL
(4 I SOH
REFORMmiddot - FC( ATE GASO
EXTRACT HTRACT
FCC GASO FRAC RE FORM
BTX SALES
000 8D HISE ETOH I $(raquo-I ALKYL TOTAL
11 111 V VI
bull IV
Topping Hydrosk iITTning Conv bull 0 Conv D Conver s 1 on 0 Convrr-ion
IA N Cal
00 00 00 00 7 7
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 n 1 00 110
00 00 00 00 00
00 36
161 207 86
Oll 00 ~ i 30 114
oo 00 -2 72 00
00 00 2 1 00 59
00 00 08 00 65
00 00 00 00 19
00 00 00 00
130
00 00 00 00 00
00 LlO 18 0 D 4 3
00 00 6~
1 Z 7 116
00 no Ll0 00 00
00 00 00 00 00
00 2 1 00 0 0 00
00 2 1 64
12 7 116
IClT Al CALIFORNIA 7 7 00 00 00 00 03 00 490 11 1 134 8 14 5 1 9 130 00 6 1 306 Ll0 0 D 2 1 32
1) X RPd11rt1nn from Rnsr Cc1~C Ar11fl1i1t1rs lrvrl
--a--1~-~ --j-J
~ P gt t sect p t-$-- p
H 1995 DIESEL RESULTS
~ gti =shyc p C ~i
-p
1995 Diesel Aromatics amp Sulfur Results middot Surmary Diesel with Investment
D I E S E L REFINERY COST CHANGES
DESCRIPTION AROMATICS
REDUCT ION PROO
000 8D
2 2 SULFUR
111 CETANE
NO
POLY AROM VOL
TOTAL AROM VQL
HET FEED ST
000 $D
VAR COST
000 $D
FJXED COST
000 $0
CAPITAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG bullbull MILLION $ ENERGY
000 80
Base Case with 1 nves tment 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
05 Sul fur 309 1 005 445 64 296 6935 306 61 1 2082 9934 7 7 2914 2195
f I-
20 Aromatics
15 Aromatics
10 Aromatics
341
52 5
672
3091
3091
3091
014
007
0030
487
495
508
37
17
03
200
150
100
1136
2594
25969
467
105 4
243 7
639
1393
370 7
2962
6066
11429
5204
11108
43543
4 0
86
335
414 7
8492
16001
387
742
8721
DESCR IPT IOH NAP HT
HOT
PROCESS
DIST DIST HOT HR
AODITIOHS
AROM H2 HOA PLANT
000 80
MOBIL MOBIL OLEF IHS t-lOGD
PURCHASED STOCKS
SO LA GAS 01 L 000 8D
Base Case with Investment 00 00 21 00 00 00 00 00
05 Sul fur 15 309 974 00 00 00 00 00
20 Aromatics 31 00 611 1108 00 08 08 00
15 Aromatics 9 7 00 1066 1736 353 15 6 156 00
10 Aromatics 53 00 1633 2255 1370 724 724 00
1) frac34 Aromatics Reduction from Base Case Aromatics Level
middot~~-~-
~ 17 gt ~ s ~ C Jr-= fl
1995 Diesel Aromatics amp Sulfur Results middot Base Case with Investment
DIESEL REFINERY COST CHANGES MEMO
POLY TOTAL NET VAR FIXEO CAPITAL TOTAL TOTAL BASE CASE AROMATICS PROO SULFUR CETANE ARDM ARDM FEEDST COST COST COST COST COST INVEST ENERGY JMNVESTMENT
GROOP DESCRIPTION REDUCTION 000 BD IIT NO VOL VOL 000 SD 000 SD 000 $D 000 $D 000 $D CPG bullbull MILLION S 000 8D MILLION S
I Topping 00 22 1 032 41 1 85 288 00 00 00 00 00 00 00 middot 000 00
11 Hydrosk i rmi ng 00 190 032 41 1 85 288 00 00 00 00 00 00 00 000 00
c I
111 bull V
V Conv + D Conv 0 Conversion LA
00 00
131 1 43 2
019 048
439 489
61 120
322 362
00 00
00 00
00 00
00 00
00 00
00 00
00 00
000 000
00 00
N VI D Conversion N Cal 00 616 018 438 79 276 00 00 00 00 00 00 00 000 119
TOT AL HIGH SUL FUR 00 277 0 0 25 442 78 313 00 00 00 00 00 00 00 000 119 TOTAL CALIFORNIA 00 3091 023 443 76 310 00 00 00 00 00 00 00 000
PROCESS ADDITIONS 000 BD PURCHASED STOCKS
SO LA NAPHTHA DIST DIST ARDM H2 MOBIL MOBIL GAS 01 L
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLE FINS MOGO 000 8D
Topping 00 00 00 00 00 00 00 00 II Hydroskirming 00 00 00 0 0 00 00 00 00 111 bull IV Conv + D Conv 00 00 00 0 0 00 00 00 00 V D Conversion LA 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 2 1 00 00 00 00 00
TOTAL CALIFORNIA 00 00 2 1 00 0 0 00 00 00
-__----1~bull _
~ 17 gt ~ r C p t-JDdeg -p
1995 Diesel Aromatics amp Sulfur Results bull 05 wt Sulfur with Investment
DIESEL REFINERY COST CHANGES
GROUP DESCRIPTION SULFUR PROD
000 BD SULFUR
IT CETANE
NO
POLY AROH VOL
TOTAL AROH VOL
NET FEEDST
ODO SD
VAR COST
000 $0
FIXED COST
000 $D
CAPITAL COST
000 S0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG HILLION $
ENERGY 000 B0
r I
w
I II Ill + V VI
IV
Topping Hydroskinming Conv + D Conv D Conversion D Convers on
LA N Cal
005 005 005 005 005
22 1 190 790 432 391
005 005 005 005 005
36 7 399 475 489 45 1
46 60 56 75 72
205 26 7 279 309 302
-S102 1237 103 68 41
105 25 45
101 18
289 103 122 185
5 2
292 193 902 386 295
5788 1558 1173
741 406
624 195 35 41 2 5
408 270
1263 541 413
1540 436 029 000 014
TOTAL HIGH SULFUR TOTAL CALIFORNIA
005 0 05
2024 3091
005 0 05
455 445
62 64
280 296
6551 6935
295 306
75 1 611
2068 2082
9665 9934
114 77
2895 2914
2034 21 95
GROUP DESCRIPTION
PROCESS
NAPHTHA DI ST HDT HOT
ADDITIONS
01S1 ARDM HR7 HOA
HZ PLANT
000 8D
MOBIL OLEFINS
PURCHASED STOCKS
SO LA MOBIL GAS DI L
HOGD 000 80
I II III V VI
+ IV
Topping Hydrosk inmi ng Conv + 0 Conv D Conversion D Conversion
LA N Cal
00 00 00 1 5 00
309 00 00 00 00
00 75
472 184 243
00 00
14 7 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 15 309 974 14 7 00 00 00 00
~ 17 gtI-E 0 t ~ F -ri
1995 Diesel Aromatics amp Sulfur Results middot 20 Aromatics with Investment
DIESEL REFINERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCTION PROD
000 B0 SULFUR
IT CETANE
NO
POLY AROM VOLfrac34
TOTAL AROK VOL
MET FEEDS
000 SD
VAR COST
000 S0
FIXED COST
000 SD
CAPITAL COST
000 SD
TOTAL COST
000 $D
TOTAL COST I MVEST
CPG MILLION S ENERGY
000 BD
c i ~
I 11 111 V VI
+ IV
Topping Hydrosk i rrmi ng Conv + D Conv D Conversion D Conversion
LA N Cal
-107 306 363 448 275
221 190
1311 753 616
039 013 011 014 010
53 1 52 0 486 474 477
49 43 30 41 40
200 200 200 200 200
(10) (08) 609 172 373
24 20 69
290 63
85 69 15
346 124
397 368
1105 465 627
497 449
1798 1273 1188
5 4 56 33 40 46
556 51 5
154 7 651 878
(008) (007) 227 000 116
TOTAL CALIFORNIA 344 3091 014 487 37 200 1136 46 7 639 2962 5204 40 414 7 387
GROOP DESCRIPTION
PROCESS
NAPHTHA 01 ST HDT HOT
ADDITIONS
DIST AROH HR7 HOA
HZ PLANT
000 8D
MOBIL OLEF INS
PURCHASED STOCKS
SO LA MOBl GAS 01 L
MOGO 000 80
I II 111 V VI
+ IV
Topping Hydroskirrming Conv + O Conv O Conversion O Conversion
LA N Cal
oo 00 00 31 oo
00 0 0 00 00 00
50 56
289 04
213
49 5 5
47 1 32 1 212
00 00 00 00 00
04 04 00 00 00
04 04 00 00 00
00 00 00 00 00
TOTAL CALIFORNIA 31 00 61 1 1108 00 08 08 00
17 gtl =shyc p t-JtJ-= ) 1995 Diesel Aromatics amp Sulfur Results middot 15 Aromatics with Investment
DIESEL REF I NERY COST CHANGES
POLY TOTAL NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROO SULFUR CETANE AROM AROM FEEOST COST COST COST COST COST INVEST ENERGY
GROUP DESCRIPTION REDUCT ION 000 90 WT) NO VCL VOL) 000 S0 000 S0 000 $0 000 $0 000 S0 CPG MILLION S 000 B0
I Topping 330 221 007 487 14 150 (84) 142 299 1125 1481 160 1575 (092)
II Hydroskinming 479 190 002 499 20 150 (71) 12 0 243 983 127 5 160 1376 (077)
II I + IV Conv + D Conv 52 3 131 1 009 504 15 150 1051 135 11 2 1592 2891 52 2229 400
c I
V VI
D Convers on D Conversion
LA N Cal
586 45 7
753 616
004 008
483 491
17 22
150 150
487 121 1
398 259
502 237
838 1528
222 5 3236
70 125
1173 2139
000 332
V TOT AL CALI FORNI A 508 309 I 007 495 1 7 150 2594 1054 1393 6066 11108 86 8492 742
PROCESS ADDITIONS 000 BID PURCHASED STOCKS
SO LA NAPHTHA DI ST DI ST AROM H2 MOBIL MOBIL GAS OIL
GROUP DESCRIPTION HOT HOT HR7 HOA PLANT OLEFIHS MOGO 000 8D
I Topping 00 00 77 72 168 39 39 00 II Hydroskinming 00 00 84 79 185 4 3 43 00 III + IV Conv + D Conv 00 00 478 846 00 00 00 00 V 0 Conversion LA 30 00 140 456 00 00 oo 00 VI D Conversion N Cal 6 7 00 287 284 00 7 5 75 00
TOTAL CALIFORNIA 97 00 1066 1736 353 156 156 00
~ P gt tr i -I
p t ~~ -)
1995 Diesel Aromatics amp Sulfur Resultsmiddot 10 Aromatics with Investment
DIESEL REF NERY COST CHANGES
GROOP DESCRIPTION AROMATICS
REDUCT ION PROD
000 BD SULFUR
IITX CETANE
NO
POLY AROM VOL
TOTAL AROM VOL
NET FEED ST
000 SD
VAR COST
000 S0
f JXED COST
000 SD
CAP TAL COST
000 $0
TOTAL COST
000 $0
TOTAL COST INVEST
CPG MILLION $ ENERGY
000 80
r I
deg I II Ill + V VI
IV
Topping Hydrosk inrni ng Conv + D Conv D Conversion 0 Conversion
LA N Cal
55 4 653 682 724 638
22 1 190
131 1 75 3 616
0003 0001 0049 0000 0043
512 51 2 517 489 509
07 07 02 02 05
100 100 100 100 100
9596 8097 2900 2446 2930
435 36 7 397 615 623
1132 922 509 690 455
2080 1803 2888 2459 2200
13243 11189
6694 6210 6207
1427 1402
122 196 240
2912 2524 4043 3442 3080
3328 2808 1058 000 795
TOTAL CALIFORNIA 672 3091 0030 508 03 100 25969 2437 3707 11429 43543 335 16001 8721
GROOP DESCRIPTION NAPHTHA
HOT
PROCESS
DI ST HDT
ADDITIONS
DI ST AROM H2 HR HOA PLANT
000 BD
MOB L OLE FINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II 111 V VI
+ IV
Topping Hydrosk i nrni ng Conv + 0 Conv D Conversion O Conversion
LA N Cal
00 00 00 5 3 00
00 00 00 00 00
10 1 111 630 444 348
95 106
1136 574 344
57 0 62 7
00 173 00
12 2 136 12 1 128 21 7
122 136 12 1 128 217
00 00 00 00 00
TOTAL CALI FORNI A 53 00 1633 225 5 1370 724 724 00
CJ)
j gt CJ)
w Pc
rii z H -iJ
I 0 CJ)
~ c
LI)
deg -1 deg
H
A~ Arthur D Little Inc
~--=amp-
f7 gtI s r C--ji -P 1995 Gasoline Aromatics amp Benzene Results - Surmary Gasoline with lnvestment
H I
I-
DESCR I PT ION
Base Case with 1 nves tment
Max Aromatics Recuct ion
Max Aromatics Recuct ion wPurch
AROMATICS REDUCTION
00
147
Fee 503
MOTOR GASOLINE
PROO AROM BENZ 000 8D VOL VOL
8318 32 3 188
8318 275 161
8318 161 081
NET FEEDST
000 $0
00
10281
46634
REF I NERY COST CHANGES
VAR FIXED CAPITAL TOTAL COST COST COST COST
000 $0 000 $0 000 $0 000 $0
00 00 00 00
222 7 6880 13249 32637
18 1902 9050 57604
TOTAL COST INVEST
CPG MILLION $
00 00
93 18549
165 12661
ENERGY 000 8D
000
L739
571
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO HZ CAT THRU RECYCLE C4 ATE GASO GASO SALES
DESCRIPTION HOT HOT PLANT ALKYL POLY OIMERSOL SOM SOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC RE FORM 000 B0 MTBE ETOH SOM ALKYL TOTAL
Base Case with Investment 00 00 00 00 00 00 62 322 13 7 16 7 24 00 00 00 00 00 00 00 00 00 00
Max Aromatics Reduction 7 1 26 483 3 33 00 04 00 621 234 118 1242 669 130 7 1816 676 296 00 00 00 00 00
Max Aromatics Reduction wPurch Fee 29 119 2175 00 00 00 00 491 27 00 139 1301 127 8 1469 00 463 616 75 00 1086 1581
1) Reduction from Base Case Aromatics Level
=cf~---
17 gtl 2 l
p C Jii -p
1995 Gasoline Aromatics amp Benzene Resultsmiddot Base Case with Investment
H I
N
GRIXJP DESCRIPTION
I Topping II Hydrosk i rrmi ng I I I + IV Conv + D Conv V D Conversion VJ D Conversion
TOTAL CALI FORNA
AROMATICS REDUCTION
00 00
LA oo N Cal 00
00
MOTOR GASOLINE
PROO AROM BENZ 000 80 VOL VOL
186 393 27 3202 306 8 2606 314 1 7 2324 350 20
8318 323 9
NET FEEDST
000 $D
00 00 00 00
00
REFINERY COST CHANGES
VAR FJXED CAPITAL TOTAL COST COST COST COST
000 S0 000 $0 000 $D 000 $0
00 00 00 00 00 00 o 0 00 00 00 00 00 00 00 00 00
00 00 00 00
TOTAL COST INVEST
CPG MILLION $
00 00 00 00 00 00 00 00
00 00
ENERGY 000 B0
00 00 00 00
00
MEMO BASE CASE INVESTMENT MILLION $
202 897 798 460
235 7
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 80
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GRIXJP DESCRIPTION HOT HDT PLANT ALKYL POLY DJMERSOL SOM ISOM HTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 80 HTBE ETOH SOM ALKYL TOTAL
Topping II Hydrosk i rrmi ng 00 00 00 00 00 00 00 35 00 00 00 00 00 0 0 00 0 0 00 00 00 00 00 111 + IV Conv + D Conv 00 00 00 00 00 00 62 69 40 65 00 00 00 00 00 00 00 00 0 0 00 00 V D Conversion LA 00 00 00 00 00 00 00 218 00 56 24 00 00 00 00 00 00 00 00 00 00 VI D Conversion N Cal 00 00 00 00 00 00 oo 00 97 46 00 00 00 00 00 00 00 00 00 00 00
TOTAL CALI FORNI A 00 00 00 00 00 00 62 322 13 7 167 24 00 00 00 00 00 00 00 00 00 00
~se I
~ P gtlr = i C JS-0 ri
1995 Gasoline Aromatics amp Benzene Results bull Max Aromatics Reduction with Investment
MOTOR GASOLINE REFINERY COST CHANGES
NET VAR FIXED CAPITAL TOTAL TOTAL AROMATICS PROD AROM BENZ FEEDST COST COST COST COST COST INVEST ENERGY
GROOP DESCRIPTION REDUCTION 000 BD VOL vou 000 $0 000 SD 000 SD 000 SD 000 $0 CPG MILLION $ 000 80
I Topping
H II Hydrosk i rnni ng 49 186 374 38 370 28 118 334 850 109 467 12 I I II + IV Conv + D Conv 120 3202 269 14 3004 306 1729 4082 9121 68 5715 139
w V D Conversion LA 169 2606 261 1 8 5373 1139 3029 4982 14523 133 6974 217 VI 0 Conversion N Cal 168 2324 291 15 1534 753 2004 3852 8143 83 5393 106
TOTAL CAL FORNI A 147 8318 27 5 16 10281 222 7 6880 13249 32637 93 18549 474
PROCESS ADDITIONS 00080 PURCHASED FEEDSTOCK 000 B0
FCC ONCE RE FORKmiddot FCC FCC 8TX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROUP DESCRIPTION HOT HOT PLANT ALKYL POLY DI HER SOL ISOM ISOM HT8E ETHEROL ISOM EXTRACT EXTRACT FRAC RE FORM 000 B0 HTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk irnning 00 00 30 00 00 00 00 38 00 00 38 1 7 00 00 00 00 00 00 00 00 00 111 + IV Conv + D Conv 00 26 887 00 00 04 00 226 57 62 603 5 3 52 7 408 428 91 00 00 00 00 00 V D Conversion LA 00 00 3531 00 00 00 00 242 76 55 335 52 7 296 503 00 11 7 00 00 00 00 00 VI D Conversion N Cal 7 1 00 385 33 00 00 00 115 101 00 265 7 1 484 90S 248 8 7 00 00 00 00 00
TOTAL CALIFORNIA 71 26 4833 33 00 04 00 621 234 11B 124 2 669 1307 1816 676 296 00 00 00 oo 00
1) Reduction from Base Case Aromatics Reduction Level
17 gt ~ r = I
~ t + +-JD-sl 1995 Gasoline Aromatics amp Benene Resultsmiddot Max Aromatics Reduction with Investment amp Purchased Feedstock
H I
-P-
GROOP DESCRIPTION
I Topping II Hydroskirrming III + IV Conv + D Conv V D Conversion VI D Conversion
TOTAL CALIFORNIA
AROMATICS REDUCTION
672 480
LA 628 N Cal 379
503
MOTOR GASOLINE
PROD AROM BENZ 000 BD VOL VOL
186 129 15 3202 158 08 2606 117 05 2324 217 11
8318 16 1 08
NET FEED ST
ODD $0
1429 16347 17477 11381
46634
REF I NERY COST CHANGES
VAR FJXED CAP ITAL TOTAL COST COST COST COST
000 $0 000 $0 ODO $0 000 $0
(32) (124) 92 1364 (34 5) 218 3216 19436 (21) 579 2998 21032 41 7 1230 2744 15772
18 1902 9050 57604
TOTAL COST INVEST
CPG bullbull MILLION $
175 152 14 5 4414 192 419 7 162 3899
165 12661
ENERGY 000 BD
08 (35) 36 49
57
PROCESS ADDITIONS 0008D PURCHASED FEEDSTOCK 000 B0
FCC ONCE REFORMmiddot FCC FCC BTX NAPHTHA GASO H2 CAT THRU RECYCLE C4 ATE GASO GASO SALES
GROOP DESCRIPTION HOT HOT PLANT ALKYL POLY DIMERSOL ISOM ISOM MTBE ETHEROL I SOM EXTRACT EXTRACT FRAC REFORM 000 8D MTBE ETOH ISOM ALKYL TOTAL
I Topping II Hydrosk i rrmi ng 00 00 04 00 oo 00 00 35 00 00 00 07 00 00 00 03 00 00 00 60 60
111 + IV Conv + D Conv 00 119 1282 00 00 00 00 168 2 7 00 101 314 422 35 0 00 135 200 2 2 00 194 220
V D Conversion LA 00 00 264 00 00 00 00 198 00 00 00 702 463 382 00 196 161 00 00 731 892
VI D Conversion N Cal 29 00 626 00 00 00 00 90 00 00 38 27 8 394 736 00 128 256 5 3 00 10 1 410
TOTAL CALIFORNIA 29 119 2175 00 00 00 00 491 27 0 0 139 1301 127 8 1469 00 463 616 7 5 00 1086 1581
1) Reduction from Base Case Aromatics Reduction Level
~j ~
~ l7 gt ~ r C I
C ~
F-i p
J 1995 DIESEL AND GASOLINE COST EQUATIONS
- -~ 9 c_-~-- C ~
P gtIr = 1
C ~rS -fl
Li I
I---
GROUP I COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
DIESEL RUNS
BC with Investment 000 000 000 000 000 05 wt Sulfur wlnv 20 Aromatics wInv
2309 (005)
048 011
131 038
132 180
2620 224
15 Aromatics wInv 10 Aromatics wInv
(038) 4342
064 197
135 5 12
509 941
670 5992
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
29-Jul-88
~J -
17 gt 1 i- p C
=
Jll- -)
Li I
N
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wlnv 15 Aromatics wInv 10 Aromatics wInv
GASOLJ NE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP II COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 ODO 000 000 000 651 013 054 102 820
(004) 0 11 036 1 94 237 (0 37) 063 128 5 17 6 71 4262 193 485 949 5889
000 000 000 000 000 199 0 15 063 180 457 768 ( 0 17) (067) 049 733
29-Jul-88
~ 17 gtIr C -i
D CJS-l r
GROUPS III amp IV COST
Feedstock
EQUATION COMPONENTS
Variable
FOR 1995 $ B
Fixed Capital Total
DIESEL RUNS
BC with Investment 05 wt Sulfur wlnv 20 Aromatics wlnv 15 Aromatics wlnv 10 Aromatics wlnv
000 013 046 080 221
000 006 005 010 030
000 015 001 009 039
000 114 084 121 220
000 148 136 220 5 10
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wlnv ampPurch Feed
000 094 511
000 010
(011)
000 054 070
000 127 100
000 285 670
c I
w
29middot Jul-88
pound-= -middot
17 gtI r C l
~ C u-
-fl
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv amp Purch Feed
c I
--
GROUP V COST EQUATION
Feedstock
000 016 023 065 325
000 206 6 71
COMPONENTS FOR
Variable
000 023 039 053 082
000 044
(001)
1995 $ B
Fixed
000 043 046 067 092
000 116 022
Capital
000 089 062 1 11 327
000 191 115
Total
000 1 71 1 70 296 826
000 557 807
29-Jul-88
-r--e---r-
~ 17 gtI r i I
--~ C
~~ -fl
L I
u
DIESEL RUNS
BC with Investment 05 wt Sulfur wInv 20 Aromatics wInv 15 Aromatics wInv 10 Aromatics wInv
GASOLINE RUNS
BC with Investment Max Aromatics Red wInv Max Aromatics Red wInv ampPurch Feed
GROUP VI COST EQUATION COMPONENTS FOR 1995 $ B
Feedstock Variable Fixed Capital Total
000 010 061 197 476
000 005 010 042 101
000 013 020 038 074
000 075 102 248 357
000 103 193 525
1008
000 066 490
000 032 018
000 086 053
000 166 1 18
000 350 679
29-Jul-88
--D1-c1
f7 gt1 0-= 1
I= C-Jr-- ri
K 1991 REFINERY EMISSION RESULTS
middot-__ _----d---==-
1991 Diesel and Aromatics Refinery Emissions Analysis middot SJTfllary Diesel without Investment
17 gt =-= p t -middot ~ ~-= f)
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
25 wt Sulfur
20 wt Sulfur
Diesel Prod 000 B0
2917
2917
2917
NOx
00
(193777)
(169008)
REFINERY
SOX
00
(350465)
(226981)
EMISSIONS 0
co
00
(19833)
(17276)
voe Particulates
oo 00
(842) (28492)
(734) (20077)
Max Sulfur Reduction 2917 (168333) (200364) C17084) (726) (20063)
5 Aromatics Reduction 2917 64319 369252 1 1662 496 6287
Max Aromatics Reduction 2917 66302 375386 12229 520 6329
I
r-
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Diesel Prod 000 B0
2917
NOX
2469743
REFINERY
SOX
3839205
EMISSIONS
co
346916
0
voe
14744
Particulates
387832
25 wt Sulfur 2917 2202719 3734913 290242 12336 33 1049
20 wt Sulfur 2917 2227488 3858397 292799 12444 339464
Max Sulfur Reduction 2917 2228163 3885014 292991 12453 339479
5 Aromatics Reduction 2917 2534062 4208457 358578 15240 394119
Max Aromatics Reduction 2917 2539052 4223896 360004 15300 394226
~gt-c-1 ]la---
1991 Diesel and Aromatics Refinery Emissions Analysis middot Surrnary Diesel with Investment
17 gt r i= O
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
C Base Case with Investment 2917 00 00 00 00 00
ji- 15 wt Sulfur 2917 (178866) (296612) (17879) (760) (24095)
fl 05 wt Sul fur 2917 (186389) (107123) (17220) (732) (28720)
20 Aromatics 2917 33193 336076 7892 335 577
15 Aromatics 291 7 74898 395314 19162 814 (4214)
10 Aromatics 2917 138338 53717 34888 1482 (6219)
10 Aromatics at 05 Sulfur 2917 128139 244904 33584 1426 (6546)
10 Aromatics Purch Feedstock 2917 39647 299922 15851 673 (12172)
~ N REFINERY EMISSIONS D
Diesel Prod CASE EMISSIONS 000 BD NOx SOX co voe Particulates
DESCRIPTION
Base Case with Investment 2917 2471692 3566893 347358 14764 386575
15 wt Sulfur 2917 2187829 3573977 283628 12054 334243
05 wt Sulfur 2917 2212232 3673579 293325 12467 329429
20 Aromatics 291 7 2504885 3902969 355250 15099 387152
15 Aromatics 2917 2546590 3962207 366520 15577 382361
10 Aromatics 2917 2610030 3620609 382246 16245 380357
10 Aromaticsc at 05 Sulfur 291 7 2599831 3811796 380942 16190 380030
10 Aromatics with Purch Feedstock 2917 251 1339 3866815 363209 15437 374403
J-S---=iJ-frac14=
1991 Diesel and Aromatics Refinery Emissions Analysis - Diesel Segregation Cases
~ f7 gtI r C I
~ C-Jl- ri
Increase (Decrease) vs Base case
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wInvestment
NPRA Diesel Segregation 10 Aromatics wInvestment
Diesel Prod 000 8D
2917
2917
NOx
(200TT9)
1on1
REFINERY
SOX
(81658)
413423
EMISSIONS D
co
(20803)
19591
voe Particulates
(884) (29619)
832 565
50 Diesel Segregation 05 Sulfur wlnvestment 2917 22224 380709 6897 292 501
50 Diesel Segregation 10 Aromatics wJnvestment 2917 58741 371081 16584 704 (566)
CASE EMISSIONS Diesel Prod
000 8D NOX
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I
w
DESCRIPTION
NPRA Diesel Segregation 05 Sulfur wlnvestment 2917 2198085 3817697 289692 12313 329392
NPRA Diesel Segregation 10 Aromatics wlnvestment 2917 2517180 2951005 459812 19542 424935
50 Diesel Segregation 05 Sulfur wlnvestment 2917 2214389 3815495 295143 12543 329260
50 Diesel Segregation 10 Aromatics wJnvestment 2917 2505150 2908663 456806 19414 423805
1991 Diesel and Aromatics Refinery Emissions Analysis - Base Case without Investment
~ f7 gt =shy~ c 1
~ t JS
Increase (Decrease) vs Base case REFINERY EMISSIONS D -= r Diesel Prod -----------==---------~GROUP DESCRIPTION 000 BD middotmiddot- - io voe ParticulatesNUX sux
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
1237 716 577
00 00 00 00 00
00 00 oo 00 00
00 00 00 00 00
00 00 00 00 oo
00 00 00 00 00
TOTAL CALIFORNIA 2917 00 00 00 00 00
~ I
+- CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II 111 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
20196 30636
1251140 404984 762788
62649 95035
1914459 367866
1399197
5770 8753
163923 86173 82296
245 372
6967 3662 3498
433 657
196995 80497
109251
TOTAL CALIFORNIA 2917 2469743 3839205 346916 14744 387832
=-1
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 25 wt Sulfur without Investment
f7 gt ~ -
=~ p C---~ Increase (Decrease) vs Base case - REFINERY EMISSIONS D~ Diesel Prod
GROUP DESCRIPTION 000 BD NOx sax co voe Particulates
I Topping 208 00 00 00 00 00 II Hydroskimming 179 00 00 00 00 00I II + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 9061 2 1468 1997 85 1468 VI D Conversionmiddot N Cal 577 1492 2797 185 08 (186)
TOTAL CALIFORNIA 2917 (193777) (350465) (19833) (842) (28492)
7 I REFINERY EMISSIONS 0
u Diesel Prod CASE EMISSIONS 000 BD NOx sax co voe Particulates
I Topping 208 20196 62649 5770 245 433 II Hydroskimming 179 30636 95035 8753 372 657 111 + IV Conv + D Conv 1237 973563 1785902 105067 4466 138930 V D Conversion LA 716 414045 389334 88170 374 7 81965VI D Conversionmiddot N Cal 577 764280 140 1994 82481 3506 109065
TOTAL CALIFORNIA 2917 2202719 3734913 290242 12336 331049
jF___c__ bullmiddot ~
1991 Diesel and Aromatics Refinery Emissions Analysis - 20 wt Sulfur without Investment
P gtI sect
~ C F Increase (Decrease) vs Base case REFINERY EMISSIONS Df)
Diesel Prod -------=-------=------------~GROUP DESCRIPTION 000 BD NOX SOX-- co voe Particulates
I Topping 208 516 43792 148 06 1 1 II Hydroskimming 179 783 66430 224 09 1 7 II I + IV Conv + D Conv 123 7 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALI FORNI A 2917 (169008) (226981) (17276) (734) (20077)
REFINERY EMISSIONS D Diesel ProdI CASE EMISSIONS 000 BD NOX SOX co voe Particulatesdeg
I Topping 208 20712 106441 5918 252 444 II Hydroskimming 179 31420 161465 8977 382 674 III + IV Conv + D Conv 1237 986744 1818788 105656 449 1 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversion N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALI FORNI A 2917 2227488 3858397 292799 12444 339464
1991 Diesel and Aromatics Refinery Emissions Analysis middot Max Sulfur Reduction without Investment
17 gt ~
= ~ ~ D C---~-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D
Diesel Prod GROUP DESCRIPTION 000 8D NOx sax co voe Particulates
Topping 208 784 54367 224 09 1 7 II Hydroskimming 179 1190 82472 340 14 26 II I + IV Conv + D Conv 1237 (191148) (341844) (21425) (910) (23706) V D Conversion LA 716 9000 (23973) 3130 133 (978) VI D Conversionmiddot N Cal 577 11840 28613 647 28 4578
TOTAL CALIFORNIA 2917 (168333) (200364) (17084) (726) (20063)
7 I REFINERY EMISSIONS D
-I Diesel Prod CASE EM SSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 20980 117016 5994 255 450 JI Hydroskimming 179 31826 177507 9093 387 682 I II + IV Conv + D Conv 1237 986744 1818788 105656 4491 144999 V D Conversion LA 716 413984 343893 89303 3795 79519 VI D Conversionmiddot N Cal 577 774628 1427810 82944 3525 113829
TOTAL CALIFORNIA 2917 2228163 3885014 292991 12453 339479
F-ibullbull---bull j
1991 Diesel and Aromatics Refinery Emissions Analysis - 5 Aromatics Reduction without Investment ~ 17 gtrc p C y~- ri Increase (Decrease) vs Base case
Diesel Prod REFINERY EMISSIONS D
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 1115 46107 319 1 3 24 II III+ IV
Hydroskimming Conv + D Conv
179 1237
169 1 40358
69942 237625
483 6918
20 294
37 2774
V D Conversion LA 716 9315 (13515) 3295 140 ( 1128) VI D Conversion - N Cal 577 11840 29093 647 28 4579
TOTAL CALIFORNIA 2917 64319 369252 11662 496 6287
REFINERY EMISSIONS D ~ I
o CASE EMISSIONS Diesel Prod
000 8D NOx SOX co voe Particulates
I Topping 208 2131 1 108755 6089 259 457 II II I + IV
Hydroskimming Conv + D Conv
179 1237
32327 1291497
164976 2152084
9236 170840
392 7261
693 199769
V D Conversion - LA 716 414299 354351 89469 3802 79369 VI D Conversion - N Cal 577 774628 1428290 82944 3525 113830
TOTAL CALIFORNIA 2917 2534062 4208457 358578 15240 394119
1991 Diesel and Aromatics Refinery Emissions Analysis - 10 Aromatics Reduction without Investment
17 ~-~ e ~
p ~--F S ~
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
1115 1691
43590
46107 69942
237362
319 483
5660
13 20
241
24 37
6344
TOTAL CALIFORNIA 2917 46396 353411 6462 274 6405
7 I
frac14) CASE EMISSIONS
Diesel Prod 000 BID NOx
REFINERY
SOX
EMISSIONS
co
ID
voe Particulates
I II I II V VI
+ IV
Topping Hydroski1T111ing Conv + D Conv D Conversion D Conversion -
LA N Cal
208 179
1237 716 577
21311 32327
1133931
108755 164976
2094878
6089 9236
135291
259 392
5750
457 693
167576
TOTAL CALIFORNIA 2917 1187569 2368610 150617 6401 168726
- - r~- _-______4
1991 Diesel and Aromatics Refinery Emissions Analysismiddot Max Aromatics Reduction without Investment
~ 17 gt ~
= ~ ~
-~ C-F 5 Increase (Decrease) vs Base case p
GROUP DESCRIPTION
I Topping II HydroskilTITiing Ill + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
~
1- 0
CASE EMISSIONS
I Topping II Hydroski111Tiing l II + IV Conv + D Conv V D Conversion LA VI D Conversion - N Cal
TOTAL CALIFORNIA
Diesel Prod REFINERY EMISSIONS D
000 BD NOx SOX co voe Particulates
208 3097 52241 885 37 67 179 1691 69942 483 20 37
1237 40358 237625 6918 294 2774 716 577
9315 11840
(13515) 29093
3295 647
140 28
(1128) 4579
2917 66302 375386 12229 520 6329
Diesel Prod REFINERY EMISSIONS D
000 BD NOx -
SOX co voe Particulates
208 23293 114890 6655 283 499 179 35335 174282 10096 429 758
1237 1291497 2152084 170840 7261 199769 716 414299 354351 89469 3802 79369 577 774628 1428290 82944 3525 113830
2917 2539052 4223896 360004 15300 394226
C
r___-Jmiddot-a ---- =-1
1991 Diesel and Aromatics Refinery Emissions Analysis middot Base Case with Investment ~ f7 gt ~
= ~ -~ -~
p-[ Increase (Decrease) vs Base case
GROUP DESCRIPTION
Topping II Hydroskirrming I II + IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
f r- r-
CASE EMISSIONS
I Topping II Hydroskirrming III+ IV Conv + D Conv V D Conversion LA VI D Conversionmiddot N Cal
TOTAL CALIFORNIA
REFINERY EMISSIONS 0 Diesel Prod
000 B0 NOx SOX co voe Particulates
208 179
1237 716 577
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00 00 00 00 00 00
2917 00 00 00 00 00
REFINERY EMISSIONS D Diesel Prod
000 BD NOx SOX co voe Particulates
208 20196 62649 5770 245 433 179 30636 95035 8753 372 657
1237 1252253 1761900 164180 6978 196285 716 404984 367866 86173 3662 80497 577 763623 1279443 82481 3506 108703
2917 2471692 3566893 347358 14764 386575
~CC-
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 wt Sulfur with Investment
~ 17 l-r C l
=J t
~-- r Increase (Decrease) vs Base case Diesel Prod
REFINERY EMISSIONS D
GROUP DESCRIPTION ODO BD NOx SOX co voe Particulates
Topping 208 661 3351 1 189 08 14 I I 111 V VI
+ IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 (191148)
8250 2369
50835 (341844) (30939)
(8175)
286 (21425)
2794 277
12 (910) 119 11
21 (23706)
(647) 223
TOTAL CALIFORNIA 2917 (178866) (296612) (17879) (760) (24095)
7 i REFINERY EMISSIONS D
f- Diesel Prod N CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 20857 96160 5959 253 447 II II I + V VI
IV Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
179 1237 716 577
1002 986744 413233 765993
50835 1818788 336927
1271269
286 105656 88967 82759
12 449 1 3781 3517
21 144999 79850
108926
TOTAL CALIFORNIA 2917 2187829 3573977 283628 12054 334243
1991 Diesel Aromatics ampSulfur Results - 05 sulfur with Investment
~ 17 gt-r c li C--r5 -fl
GROUP
I II 111 + IV V VI
DESCRIPTION
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
SULFUR
005 005 005 005 005
PROD 000 8D
208 179 735 410 367
D I E S E L
SULFUR CETANE Ill NO
005 367 005 399 005 475 005 498 005 459
POLY AROM VOL
49 64 76 77 63
TOTAL AROM VOL
204 267 279 316 283
NET FEEDST
000 $D
3800 938 47
103 48
VAR COST
000 $D
92 23 1 7 98 1 0
REFINERY COST CHANGES
FIXED CAPITAL COST COST
DOD $D 000 $D
255 264 92 178 21 786
180 334 39 336
TOTAL COST
000 $D
4411 1231 870 714 433
TOTAL COST NV
CPG MILLIO
505 3 164 2 28 11 4 1 4 28 4
TOTAL TOTAL
HIGH SULFUR CALIFORNIA
005 005
1899 2917
005 005
458 449
70 68
278 294
4936 4936
239 239
587 587
1898 1898
7660 7660
96 63
26 26
~ I- w
GROUP DESCRIPTION NAPHTHA
HDT
P R O C E S S
DIST HDT
A D D I T I O N S
DIST AROM H2 HR7 HDA PLANT
000 8D
MOBIL OLEFINS
MOBIL MOGD
PURCHASED STOCKS
SO LA GAS OIL 000 8D
I II Ill+ IV V VI
Topping Hydroskirrrning Conv + D Conv D Conversion D Conversion
LA N Cal
00 00 00 00 00
272 67 00 00 00
00 00
386 173 227
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
00 00 00 00 00
TOT AL CALIFORNIA 00 339 785 00 00 00 00 00
Note Volume ampCentsGallon are based on High Sulfur Diesel volume only for Groups III V and VI
-- ~ -eZ-ci
1991 Diesel and Aromatics Refinery Emissions Analysis middot 20 Aromatics with Investment
~ 17 gt g ~
~
--~ C
F-o Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Diesel Prod GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 1445 35959 413 1 7 31 II Hydroskimming 179 2192 54548 626 26 47 III+ IV Conv + D Conv 1237 14216 154484 2708 115 1083 V D Conversion LA 716 8741 (30165) 3404 145 (147 7) VI D Conversionmiddot N Cal 577 6599 121250 740 31 893
TOTAL CALIFORNIA 2917 33193 336076 7892 335 577
~ REFINERY EMISSIONS D Diesel Prod ~ CASE EMISSIONS 000 BD NOx SOX co voe Particulates
I Topping 208 21641 98607 6183 263 464 II Hydroskimming 179 32829 149582 9380 399 704 111 + IV Conv + D Conv 1237 1266469 1916384 166888 7093 197368 V D Conversion LA 716 413724 337701 89578 3807 79019 VI D Conversionmiddot N Cal 577 770222 1400694 83221 3537 109596
TOTAL CALIFORNIA 2917 2504885 3902969 355250 15099 387152
1991 Diesel and Aromatics Refinery Emissions Analysis middot 15 Aromatics with Investment
17 gt ~
= ~ ~ D C--F ~
~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 BD NOx SOX co voe Particulates
I Topping 208 6278 80940 1794 76 135 II Hydroskimming 179 9523 122783 2721 115 204 II I + IV Conv + D Conv 1237 27011 127461 5877 250 (1679) V D Conversion LA 716 19361 (36380) 6829 290 (182 6) VI D Conversion middot N Cal 577 12725 100510 1942 82 (1047)
TOTAL CALIFORNIA 2917 74898 395314 19162 814 (4214)
7 I
f- V REFINERY EMISSIONS D
Diesel Prod CASE EM ISS IONS 000 BD NOx SOX co voe Particulates
I Topping 208 26474 143589 7564 321 567 II Hydroskimming 179 40159 217817 11474 488 86 1 II I + IV Conv + D Conv 1237 1279264 1889361 170057 7228 194606 V D Conversion LA 716 424345 331486 93002 3953 78671 VI D Conversionmiddot N Cal 577 776349 1379954 84423 3588 107656
TOTAL CALIFORNIA 2917 2546590 3962207 366520 15577 382361
1991 Diesel and Aromatics Refinery Emissions Analysis middot 10 Aromatics with Investment
17
I-r = I
0 t~ ~
fo- r Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 BD NOx
REFINERY
sax
EMISSIONS
co
D
voe Particulates
II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
1879 1 28505
43820 25652 21569
109689 166393
C162350) 68306
(128322)
5369 8145 8756 9281 3338
228 346 372 394 142
403 61 1
(1984) (3147) (2100)
TOTAL CALIFORNIA 2917 138338 53717 34888 1482 (6219)
y I
c- -J
CASE EMISSIONS Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I I I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
208 179
1237 716 577
38987 59142
1296073 430636 785193
172338 261427
1599550 436172
115 1122
11139 16898
172935 95455 85820
473 718
7350 4057 3647
835 1267
194301 77350
106603
TOT AL CA LI FORNI A 2917 2610030 3620609 382246 16245 380357
middot-Ldeg~
1991 Diesel and Aromatics Refinery Emissions Analysismiddot 10 Aromatics at 05 wt Sulfur with Investment
~ P gt ~-~ ~ ~
p C--F 5 0
Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
II I II + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 28505
43820 25652 11371
109689 166393
C162350) 68306 62865
5369 8145 8756 9281 2034
228 346 372 394 86
403 611
(1984) (3147) (2427)
TOTAL CALIFORNIA 2917 128139 244904 33584 1426 (6546)
i
f- ---J
CASE EMISSIONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + V VI
IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversion - N Cal
208 179
123 7 716 577
38987 59142
1296073 430636 774994
172338 261427
1599550 436172
1342309
11139 16898
172935 95455 84516
473 718
7350 4057 3592
835 1267
194301 77350
106276
TOTAL CALIFORNIA 2917 2599831 381 1796 380942 16190 380030
1991 Diesel and Aromatics Refinery Emissions Analysis bull 10 Aromatics with Investment ampPurchased Feedstock v gtr c I
p C
JDdeg-~ Increase (Decrease) vs Base case REFINERY EMISSIONS D Diesel Prod
GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 8797 65745 2513 107 188 I I HydroskiITTTiing 13344 99732 162 286179 3813 I II + IV Conv + D Conv 1237 11598 45453 4892 208 (5082)V D Conversion LA 716 9085 54055 4170 177 (3044)VI D Conversionmiddot N Cal 577 (3176) 34937 462 20 (4520)
TOTAL CALIFORNIA 2917 39647 299922 15851 673 (12172)
7 REFINERY EMISSIONS D I- Diesel Prod
U) CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 28993 128394 8284 352 621 II HydroskiITTTiing 179 43980 194767 12566 534 942 Ill + IV Conv + D Conv 1237 1263851 1807353 169072 7186 191203 V D Conversion LA 716 414068 42 1921 90343 3839 77453VI D Conversionmiddot N Cal 577 760447 1314380 82944 3525 104183
TOTAL CALIFORNIA 2917 2511339 3866815 363209 15437 374403
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 05 Sulfur with Investment
17 gt
= ~ ~
~
--~ C
~ 5 Increase (Decrease) vs Base case REFINERY EMISSIONS 00 Diesel Prod
GROUP DESCRIPTION 000 80 NOx SOX co voe Particulates
I Topping 208 1941 78792 555 24 42 II Hydroskirrming 179 2944 119523 841 36 63 111 + IV Conv + D Conv 1237 (204330) (374730) (22014) (935) (29774)V D Conversion LA 716 00 00 00 00 00 VJ D Conversionmiddot N Cal 577 (1334) 94756 (185) (08) 51
TOTAL CALIFORNIA 2917 (200779) (8 1658) (20803) (884) (29619)
~ I
f- REFINERY EMISSIONS 0deg Diesel Prod
CASE EMISSIONS 000 80 NOx SOX co voe Particulates
1 Topping 208 2213 7 141440 6325 269 474 11 Hydroskirrming 179 33580 214558 9594 408 720 Ill+ IV Conv + D Conv 1237 975095 1719632 105303 4475 138947 V D Conversion LA 716 404984 367866 86173 3662 80497 VI D Conversionmiddot N Cal 577 762289 1374200 82296 3498 108755
TOTAL CALIFORNIA 2917 2198085 3817697 289692 12313 329392
1991 Diesel and Aromatics Refinery Emissions Analysis middot NPRA Segregation 10 Aromatics
f7 gtlr p C
=
-~iii Increase (Decrease) vs Base case REFINERY EMISSIONS Ds -fl Diesel Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping 208 18791 109689 5369 228 403 II Hydroskimming 179 28505 166393 8145 346 611 I I I + IV Conv + D Conv 1237 14780 4068 4125 175 465 V D Conversion LA 716 924 (50186) 843 36 (742)VI D Conversionmiddot N Cal 577 7771 183460 111 0 47 ( 172)
TOTAL CALIFORNIA 2917 70771 413423 19591 832 565
7- I REFINERY EMISSIONS D
N Diesel ProdQ CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping 208 38987 172338 11139 473 835 II Hydroskimming 179 59142 261427 16898 718 1267 II I + IV Conv + D Conv 1237 1241750 736657 261168 11100 234545 V D Conversion LA 716 405907 317680 87017 3698 79755 VI D Conversion middot N Cal 577 771394 1462903 83591 3553 108532
TOTAL CALIFORNIA 2917 2517180 2951005 459812 19542 424935
1991 Diesel and Aromatics Refinery Emissions Analysis middot 50 Segregation 05 Sulfur with Investment 17 gt ~
2 ~
~ C--F-~ Increase (Decrease) vs Base case
GROUP DESCRIPTION Diesel Prod
000 8D NOx
REFINERY EMISSIONS
sax co
D
voe Particulates
I II III V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 17 9
1237 716 577
1879 1 131 5
(1700) 5152
(1334)
109689 6537 8
120703 (9818)
94756
5369 376
(236) 1573 (185)
228 16
(10) 67
(08)
403 28 65
(47) 51
TOTAL CALIFORNIA 291 7 22224 380709 6897 292 501
7 i
N_ CASE EMISSIONS
I Topping II Hydroskimming III+ JV Conv + D Conv V D Conversion VI D Conversionmiddot
LA N Cal
Diesel Prod 000 BD
208 179
1237 716 577
NOx
38987 31952
971026 410136 762289
REFINERY EMISSIONS
SOX co
172338 11139 160413 9129
1750497 104832 358048 87746
1374200 82296
0
voe Particulates
473 835 388 684
4455 138535 3729 80450 3498 108755
TOTAL CALIFORNIA 2917 2214389 3815495 295143 12543 329260
1991 Diesel and Aromatics Refinery Emissions Analysis - 50 Segregation 10 Aromatics
17
~-~ = ~
p C--F5 p
Increase (Decrease) vs Base
GROUP DESCRIPTION
case Diesel Prod
000 8D NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II I I I V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
208 179
1237 716 577
18791 783 1
15264 9084 7771
109689 84345 4671
(11083) 183460
5369 2238 4240 3628 111 0
228 95
181 154 47
403 168 571
(1536) C17 2)
TOTAL CALIFORNIA 2917 58741 371081 16584 704 (566)
~ N N
CASE EMISSIONS
I Topping II Hydroskimming I II + IV Conv + D Conv V D Conversion VI D Conversion -
LA N Cal
Diesel Prod 000 8D
208 179
1237 716 577
NOx
38987 38467
1242234 414068 771394
REFINERY
sax
172338 179379
737260 356783
1462903
EMISSIONS
co
11139 10991
261284 89801 83591
D
voe Particulates
473 835 467 824
11105 234652 3817 78961 3553 108532
TOTAL CALIFORNIA 2917 2505150 2908663 456806 19414 423805
_plusmn_ ~
1991 Gasoline Aromatics Refinery Emissions Analysis middot Surmary Gasoline without Investment
~ P gt s ~ D C JD--= ri
7 I
N w
Increase (Decrease) vs Base case
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
CASE EMISSIONS
DESCRIPTION
Base Case without Investment
Max Aromatics Reduction
REFINERY EMISSIONS D Gasoline Prod___-=---------------c-------------
000 BD NOx sox co voe Particulates
8230 00 oo 00 00 00
8230 58895 (431003) 10965 466 8672
REFINERY EMISSIONS D Gasoline Prod
000 BD NOx SOX co voe Particulates
8230 1522167 1833103 263872 1 1214 271012
8230 158 1061 1402100 274837 11680 279684
I---___ ~lt
1991 Gasoline Aromatics Refinery Emissions Analysismiddot Surmary Gasoline with Investment
17 gt1 =-C 1
p C ~~ -ri
Increase (Decrease) vs Base
DESCRIPTION
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
case Gasoline Prod
000 BD
8230
8230
8230
NOx
00
(6332)
220632
REFINERY
SOX
00
137089
(250495)
EMISSIONS D
co
00
(795)
42852
voe Particulates
00 00
(34) 00
1821 00
Max Aromatics Reduction with Purch Feedstock 8230 (53022) (199505) (12970) (551) 00
CASE EM SS IONS Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
DESCRIPTION
I
N ~
Base Case with Investment
5 Aromatics Reduction
Max Aromatics Reduction
8230
8230
8230
1495422
1489090
1716054
1813705
1950793
1563210
256349
255553
299201
10895
10861
12716
268727
266699
284140
Max Aromatics Reduction with Purch Feedstock 8230 1442400 1614200 243379 10344 260785
~ - middot~~
1991 Gasoline Refinery Emissions Analysis - Base Case without Investment
f7 gt ~
= ~ ~
--~ ~ F $ Increase (Decrease) vs Base case REFINERY EMISSIONS D ~ Gasoline Prod
GROUP DESCRIPTION 000 BD NOX SOX co voe Particulates
I Topping II HydroskiITITiing 185 00 00 00 00 oo I I I + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion - N Cal 2307 00 00 00 00 00
TOTAL CALIFORNIA 8230 00 00 00 00 00
REFINERY EMISSIONS D I Gasoline Prod
N CASE EMISSIONS 000 BD NOx SOX co voe ParticulatesJl
I Topping II HydroskiITITiing 185 20214 62902 5775 245 433 I I I + IV Conv + D Conv 3153 458081 254587 96776 4113 88731 V D Conversion LA 2585 489155 457502 101285 4305 103541 VI D Conversion N Cal 2307 554717 1058111 60036 2551 78307
TOTAL CALIFORNIA 8230 1522167 1833103 263872 11214 271012
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction without Investment P gtI er p t Jo I ~crease (Decrease) vs Base case- REFINERY EMISSIONS Df)
Gasoline Prodmiddot----------------------c-----GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
I Topping II Hydroskimming 185 4441 36372 1269 54 95 Ill + IV Conv + D Conv 3153 14803 11596 3167 135 3053 V D Conversion LA 2585 16633 (106514) 4565 194 (00)VI D Conversion - N Cal 2307 23018 (372458) 1963 83 5523
TOTAL CALIFORNIA 8230 58895 (431003) 10965 466 8672
I REFINERY EMISSIONS D
N Gasoline Prod_deg CASE EMISSIONS 000 BD NOx Sox co voe Particulates
I Topping II Hydroskimming 185 24655 99275 7044 299 528 I II + IV Conv + D Conv 315 3 472884 266183 99943 4247 91784 V D Conversion LA 2585 505788 350989 105851 4499 103541VI D Conversion N Cal 2307 577734 685654 61999 2635 83830
TOTAL CALIFORNIA 8230 1581061 1402100 274837 11680 279684
bull -~a ~
1991 Gasoline Refinery Emissions Analysismiddot Base Case with Investment I gti
2 ~ t
~-- -ri Increase (Decrease) vs Base case REFINERY EMISSIONS D
Gasoline Prod GROUP DESCRIPTION 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 00 00 00 00 00 I II + IV Conv + D Conv 3153 00 00 00 00 00 V D Conversion LA 2585 00 00 00 00 00 VI D Conversion N Cal 2307 00 00 00 00 00
TOTAL CALI FORNI A 8230 00 00 00 00 00
N I REFINERY EMISSIONS D
---J Gasoline Prod CASE EMISSIONS 000 8D NOx SOX co voe Particulates
I Topping II Hydroskimming 185 18678 61807 5337 227 400 I I I + IV Conv + D Conv 3153 437428 259218 91934 3907 86449V D Conversion LA 2585 479360 446967 98300 4178 103624VI D Conversion N Cal 2307 559956 1045712 60778 2583 78253
TOTAL CALIFORNIA 8230 1495422 1813705 256349 10895 268727
C-~middot-
1991 Gasoline Refinery Emissions Analysis middot 5 Aromatics Reduction with Investment
~ f7 gt ~ g-1
p C ~--
Increase (Decrease) vs Base case REFINERY EMISSIONS D Gasoline Prodfl 000 BD ---------------------GROUP DESCRIPTION NOX SOX co voe Particulates
I II I 11 V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion LA D Conversionmiddot N Cal
185 3153 2585 2307
5687 (2703) (6553) (2763)
35363 (29095) 143698 (12877)
1625 (346)
(1872) (202)
69 (15) (80) (09)
122 (665) (660) (825)
TOTAL CALIFORNIA 8230 (6332) 137089 (795) (34) 00
s I
N (XJ CASE EMISSIONS
Gasoline Prod 000 BD NOx
REFINERY EMISSIONS
SOX co
D
voe Particulates
I II I II V VI
+ IV
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
24365 434726 472807 557193
97170 230123 590665
1032835
6961 91589 96427 60576
296 3893 4098 2574
522 85784
102964 77428
TOTAL CALIFORNIA 8230 1489090 1950793 255553 10861 266699
1991 Gasoline Refinery Emissions Analysis - Max Aromatics Reduction with Investment
17
Ir i I
p C F )-olt
=1 Increase (Decrease) vs Base case REFINERY EMISSIONS Dr Gasoline Prod__-----------------------=-----------------c--------
GROUP DESCRIPTION 000 8D NOx sox co voe Particulates
Topping I I Hydroskimming 185 5687 35363 1625 69 122 I II + IV Conv + D Conv 3153 62793 32831 14806 629 7627 V D Conversion LA 2585 48655 88088 13902 59 1 423 VI D Conversion - N Cal 2307 103497 (406776) 12520 532 7242
TOTAL CALIFORNIA 8230 220632 (250495) 42852 1821 00
REFINERY EMISSIONS D 7 Gasoline Prod N I CASE EM SS IONS 000 8D NOx sax co voe Particulates
1-D
I Topping II Hydroskimming 185 24365 97170 6961 296 522 I II + IV Conv + D Conv 3153 500221 292049 106741 4537 94076 V D Conversion LA 2585 528015 535054 112201 4768 104048 VI D Conversion N Cal 2307 663453 638936 73298 3115 85494
TOTAL CALIFORNIA 8230 1716054 1563210 299201 12716 284140
1991 Gasoline Refinery Emissions Analysismiddot Max Aromatics Reduction with Investment ampPurchased Feedstock
~ I gt-r C )l C--Jo-s ri
Increase (Decrease) vs Base case
GROUP DESCRIPTION Gasoline Prod
ODO BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
I II II I + IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversionmiddot
LA N Cal
185 3153 2585 2307
middot1826 (7180)
(46917) 2902
middot2251 (4462)
(35625) (157167)
middot522 (2243)
(10947) 742
middot22 (95)
(465) 32
middot39 580
(6744) (1738)
TOTAL CALIFORNIA 8230 (53022) (199505) (12970) (551) 00
7 I
w 0 CASE EM SSIONS
Gasoline Prod 000 BD NOx
REFINERY
SOX
EMISSIONS
co
0
voe Particulates
I II III+ IV V VI
Topping Hydroskimming Conv + D Conv D Conversion D Conversion
LA N Cal
185 3153 2585 2307
16852 430248 432442 562858
59556 254757 41 134 1 888546
4815 89691 87353 6 1520
204 3812 3713 261 5
361 87029 96881 76514
TOTAL CALIFORNIA 8230 1442400 1614200 243379 10344 260785
17 g-~
1
~ CJo l ri -
L 1995 REFINERY EMISSION RESULTS
q_-
1995 Diesel and Aromatics Analysismiddot Surmary Diesel with Investment
17 gt r c =
Increase (Decrease)
DESCRIPTION
vs Base case Diesel Prod
000 BD NOx
REFINERY
SOX
EMISSIONS
co
D
voe Particulates
C Base Case with Investment 753 00 00 00 00 00
JDdeg- 05 wt Sulfur 753 8473 (14931) 3564 15 1 (2109) ~ fl 20 Aromatics 753 9167 31461 4439 189 (3482)
15 Aromatics 753 17363 48169 7782 33 1 (5390)
10 Aromatics 753 34608 90882 1 1845 503 (3194)
Diesel Prod REFINERY EMISSIONS 0
DESCRIPTION 000 BD NOx SOX co voe Particulates
Base Case with Investment 753 395328 356204 82367 3501 83072 r- I
r- 05 wt Sulfur 753 403801 341273 85931 3652 80964
20 Aromatics 753 404495 387665 86806 3689 79590
15 Aromatics 753 412690 404373 90149 3831 77682
10 Aromatics 753 429936 447086 94212 4004 79878
Note Results are for Group V Only
p~
1995 Gasoline Refinery Emissions Analysismiddot Surmary Gasoline with Investment l7 l s Increase (Decrease) vs Base case REFINERY I Gasoline Prod ~ DESCRIPTION 000 BD NOx SOX C Base Case with Investment 2606 00 (00)Jo- Max Aromatics Reduction 2606 168512 3 1087 fl
REFINERY Gasoline Prod
DESCRIPTION 000 BD NOx sax
Base Case with Investment 2606 478268 430936
Max Aromatics Reduction 2606 646780 462023
r I
N
Note Results are for Group V Only
~i
EMISSIONS D
co
(00)
46470
EMISSIONS D
co
99648
146118
voe Particulates
(00) (00)
1975 6302
voe Particulates
4235 100501
6210 106803
17 _
l r = 1
p t F-= ri
M 1991 TYPICAL DIESEL AND GASOLINE BLENDS
17 gt1 c ~
I
0 C ~~ -fl
Heavy Naptha Atrospheric Light Gas Oil Atmospheric Light Gas Oi I Hydrotreated Atmospheric Heavy Gas Oil Atmospheric Heavy Gas Oil Hydrotreateltl Atmospheric Heavy Gas Oil Hydrorefinod Atmospheric Heavy Gas Oil Dearomitized Full Range Gas Oi t
Light Cat Cycle Oil i Light Cat Cycle Oil Hydrotreated
f-- Light Cat Cycle Oil Hydrorefineltl Light Cat Cycle Oil Dcaromitizcd Hydrocracker Jet Mobil Diesel PurchaslOlow Aromatics Bl ends tocks Coker Light Gas Oil Coker Light Gas Oi I Hydrot reAted Coker light Gas Oil Hydrorcfined Coker light Gas Oil Ocnr0mitized
Totnl Activity
Oicsc I Oua l i t 1cs
Specific Gravity Sul fur wtX Cetone No Hono Ar0111citics X Poly Aromatics X Total Aromatics ~
Typical High Sulfur Diesel Blendsmiddot
Max Sul fur Base Case Reduction
wo lnvestrnent wo Investment act X act X
000 001 004X 000 000 000 043 2 7X 000 000 918 5883) 1192 7641X 000 0 00 000 000 569 3647 1 10 703X 000 000 000 000 000 aco 0 00 000 o 73 470X 215 13 7BX 000 000 000 000 000 000 000 000 000 000 000 000
15 60 10000X 1560 100 oox
0 859 0 845 0 30 0 21 45 a 47 2 20 1 204
16 68 277 72
Diesel Sulfur Reduction
Base Case bull15X Sul fur with Investment with Investment
act X act X
000 000 000 000 000 053 342X 000 000 931 5968) 959 614SX 000 288 1847X 000 000 550 35 23X 000 000 000 000 000 000 044 282X 000 000 0 79 S08X 216 1384X 000 000 000 000 000 000 000 000 000 000 000 0 00
15 60 10000X 1560 10000X
0859 0 856 030 015 ftS9 t70 20 1 208 76 60
27 7 276
OSX Sul fur with Investment
act X
000 003X 000 059 376X 000 186 11 90X
1025 65 73X 000 000 000 000 073 4 71X 000 216 13BX 000 000 000 000 000 0 00
1560 10000X
0 855 005 47 2 21 1 61
27 2
-middot~ ~--C-=i
17 gt ~ r C 1
0 C F-s Typical High Sulfur Diesel Blends middot Diesel Aromatics Reduction
r
Hax Aromat ks D5 Sul fur +
Max Aromatics 25X Aromatics SOX Arcrna ti cs Mex Arcmat ics Reduction with Max Aromatics
Base Case Reoxtion Base Case Reduction Reoict ion Reduction Inves trnent and Reoiction
wo Investment act
wo Investment act X
with Investment act X
with Investment act X
with Investment act
with Investment act X
Purch act
Feros tod X
with Investment act X
2
N
Heavy Haptha Atrrospheric Light Gas Oil Atrrospheric Light Gas Oil Hydrotreated Atrrospheric Heavy Gas Oi t Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Jieavy Gas Oil Hydrorefined Atrrospheric Heavy Gas Oi I Deeromitized Fut l Range Gbulls Oil Light Cat Cycle Di t Light Cat Cycle Oil Hydrotreated Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dearomitized Hydrocracker Jet Hobi t Diesel
000 000 000 000 918 000 000 569 000 000 000 000 0 73 000
5883t
364X
1 70X
000 000 0 30 0 oo
1126 000 ooo 189 000 0 00 000 000 2 15 000
191X
n16Z
12 14X
13 79X
000 000 000 000 931 000 000 550 000 000 000 000 0 79 0 00
5968X
35 23X
508X
000 000 000 000 695 000 335 2 27 000 000 000 000 217 0 00
44SSX
2149X 1454X
1393X
000 000 000 000 158 000 787 2 74 000 000 000 030 230 082
1011
5043X 1757X
190X 14 74X 527X
010 000 037 000 000 ooo 968 177 000 000 000 000 232 135
066X
237X
6206X 1135X
1487X 868X
000 000 042 000 098 000 958 026 000 000 000 000 000 015
2rn
630X
6138t 167X
097X
010 000 032 000 050 000 956 096 000 000 000 0 12 240 088
066X
203X
323X
6130X 614X
0 75X 1536X 563X
PurchasedLow Arcmat i cs B t endstods Coker Light Gas Oi t Coker Light Gas Oil Hydrot reated Coker Light Gas Oil Hydrorefined Coker Light Gas Oi I Dearomltlzed
0 00 000 000 000 000
0 DO 0 00 OOD 000 000
000 000 000 000 000
0 00 000 000 000 086 550X
000 000 000 000 000
000 000 000 000 000
420 000 000 000 000
2695X 000 000 000 0 00 077 4 91X
Total Activity 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X 1560 10000X
Diesel Qualities
Spec l f i c GravJ ty Sulfur wtX
0859 0 30
0856 0 24
0859 0 30
0854 016
0844 012
0839 007
0846 0 05
0842 005
Cctane No sa 45 9 45 9 47 6 49 5 50 3 511 500
Mono Aromatics X Poly AromAt ics X Total Arooiatics X
20 1 76
77
199 6 5
264
201 76
277
166 4 4
206
168 1 7
135
96 04
100
90 10
100
9 7 0 3
100
middotbull-~es__middotbull ~4Cici-
~ V lr = C--F i ri
Typical Low Sulfur Diesel Ble-rds - Diesel Aromatics Reduction
Base Case wo Investment act
Max Aranatics Reduction
wo Investment act X
with act
Base Case Investment
X
25X Aromatics Reduction
with Investment act X
SOX Momet i cs Reduction
wi th Investment act X
Max Aromatics Reduction
with Investment act X
1-lax Aromatics Reduction with Investment end
Purch Feedstock act X
8
w
Heavy Haptha Atmospheric Light Gas Oil Atmospheric Light Gas Oil Hydrotreated Atmospheric Heavy Gas Oil Hydrotreated Atmospheric Heavy Gas Oi 1 Hydroref ined AtmosPeric Heavy Gas Oil OearCfflitized Full Range Gas Oil Light Cat Cycle Oil Hydrorefined Light Cat Cycle Oil Dear001itized Hydrocrecker Jet Hobi l Diesel Purchased low Aromatics Feedstocks Vi sbreaker Gas Oil Hydroref ined Visbreaker Gas Oil Dearcmitized
000 000 000 000 803 000 000 000 000 049 000 000 068 000
8731
529X
739X
0 76 000 093 000 555 000 000 000 000 092 000 000 103 000
831X
1015
6031
1002X
11 20
000 000 000 000 805 005 000 000 000 042 000 000 068 000
8747X osox
461X
741X
000 000 000 000 470 304 000 000 004 077 000 000 065 000
5106X 3300X
048X 839X
706X
000 000 000 000 103 637 000 000 038 077 000 000 065 000
11 22X 6921X
409X 840X
709X
000 000 000 000 000 731 000 000 000 068 048 000 000 073
7943X
742X 523X
792X
000 000 000 000 000 729 000 000 000 000 031 089 000 on
7921X
339X 962X
778X
Total Activity 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X 920 10000X
Diesel Qualities
Specific GrAvity Sul fur wtX Cetcme Mo Mono Aromatics X Poly Aromatics X Total Aromatics
0 851 0 050 499 222 56
278
0842 0 005 48 1 210 4 5
25 5
0852 0006 499 22 2 56
278
0frac346 0004
514 175 3 2
20 7
Ofrac34O 0002 530 128 08
136
0836 0000
53 9 99 01
10 0
0839 0006
54 0 96 04
100
---t_J--ij cJc-_
~ 17 gtIr C I
~ C-Jr-I ~
Typical Gasoline Blends middot Gasoline Aromatics Rc-ducton
Base Case with lnvestment
act X
10X Arcrnatics Redxtion
with Investment act X
20X Arcrnatics Reduction
with Investment act X
Ha-x Aromatics Reduction with
Investment amp PF act X
I
i--
Cat Ga sol i n-e Reformate Alkyl ate Dimate Cat Poly Jsomerate Haptha Lt Hydrocrackate Coker Naptha HTBE Ethanol Toluene Raffinatc BTX Hobi l Gisol lne Ethcrol Butme
2786 22 49 10 70 000 0 00 5 23 5 6l 280 3 37 000 000 000 000 000 183 5 55
32 58X 2631X 12 51X
612X 664X 327X 394X
214X 649X
2861 2685 1084 000 3 43 001 546 262 3 45 000 000 000 000 000 000 4 23
33 46X 3140X 1268
402X OOlX 638X 30X 403X
4 95X
1997 3113 1367 000 421 000 464 2 76 3 73 000 000 131 000 000 000 409
2336X 3641X 1598)
492X
543X 323) 436)
1 53X
479X
25 74 2678 872 000 316 000 627 262 7 40 000 000 085 000 000 000 396
30 lOX 3132X 1020)
369X
733X 306) 866X
099X
463X
Total Activity 8550 10000X 8550 10000X 85 50 10000X 85 50 10000X
Gasoline Qualities
Aromatics Vol Benzene Vol
34 9 18
314 197
27 6 149
276 157
N NPRA SURVEY RESULTS
1h Arthur D Little Inc
~bullbullmiddot-e--c+~l ~c-_middot_
NPRA STUDY - CALIFORNIA COSTS
17
Case Reduction of Diesel to 005 S and_20i Aromaticsgt r i Group I Group II Group III Group IV 3 Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) LA N Calif Calif - Diesel ProductionP (000 BD)-~
Diesel Base 4 130 528 11 8 207 259 1246 Common DieselDistillate 1 0 147 31 5 883 243 1589
Total Diesel 5 130 675 433 1090 502 2835
Addi tional~apac i ty
2Hydrodesulfurization 000 BD 184 167 509 120 1060 500 2540 Sulfur Recovery LTD 12 4 2 0 20 0 38 H Generation MSCFD 190 100 100 150 350 200 1090z 2
I f-
Costs (000 $D)
Operating 282 114 759 73 1531 611 33701Capital Charge 863 342 115 1 582 2342 986 6266
Total Cost 1145 456 1910 655 3873 1597 963 6
Total Cost centgal 5452 836 674 360 846 758 809
Investment Million $ 126 50 168 85 342 144 915
1 (Investment x 25)365
2 Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
-lmiddot -_--11 ~-middot1~J-
NPRA STUDY - CALIFORNIA COSTS
~ 17
Case Reduction of Diesel Sulfur to 005 I-r gt
3 I = Group I Group II Group III Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total C Topping ming Conversion (FCC only) IA N Calif Calif
F - Diesel Production -(000 BD)-= ri Diesel Base 37 130 537 11 8 387 254 1463 Common DieselDistillate 0 0 148 31 5 704 243 1410
Total Diesel 37 130 685 433 1091 497 2873
Additi~nal Capacity
2 2Hydrodesulfurization 000 BD 111 157 121 80 400 195 1064 Sulfur Recovery LTD 150 40 10 0 100 0 390 H Generation MSCFD 21 0 20 10 0 50 0 90
2z I
N Costs (000 $D)
Operating 420 72 343 59 509 234 16371Capital Charge 699 267 300 179 836 103 2384
Total Cost 111 9 339 643 238 1345 337 4021
Total Cost centgal 720 621 223 1 31 294 161 333
Investment Million $ 102 39 42 25 122 15 345
1 (Investment x 25)365
2 Including 8000 BD hydrocracker
3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis
1--i~-~~ fa--__~middot-1
NPRA STUDY - CALIFORNIA COSTS
~ f7 gt Case Reduction o_f Diesel Sulfur tQ_0__15 ~
E Group I Group II Group III 3Group IV Group V Group VI ~ Hydroskim- Deep Conv Deep Conv Deep Conv Total t J5-t Diesel Production
(000 BD)
ToEEig ming Conversion (FCC only) LA N Calif Calif
r Diesel Base 39 132 539 118 526 254 1608 Common DieselDistillate 0 0 150 31 5 564 243 1272
Total Diesel 39 130 689 433 1090 497 2880
z I
w
Hydrodesulfurization Sulfur Recovery LTD H Generation MSCFD2
Costs (000 $D)
000 BD 2111140 190
143 40 20
121 80 1 0
0 0 0
350 100 40
31 0 0
756 360 260
Operating 1Capital Charge Total Cost
240 623 863
50 267 31 7
294 274 568
0 0 0
469 767
1236
121 0
121
117 4 1931 3105
Total Cost centgal 527 5 72 1 96 0 270 058 257
Investment Million$ 91 39 40 0 112 0 282
1
2
(Investment x 25)365
Including 8000 BD hydrocracker 3 Group IV includes one Group VI refinery to maintain confidentiality of data on a minimum 3 refinery basis