Natural Gas Processing - 2010

Natural Gas Processing Qualifications and Experience 2010

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Table of Contents Section 1 – Summary of Qualifications Section 2 – Gas Processing Capabilities Section 3 – Gas Processing Technology Section 4 – Project Experience & Selected Profiles


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Section 1 Summary of Qualifications Aker Solutions has specialized in projects for the natural gas industry for over 40 years. We have substantial expertise in all areas of gas production and processing including the following: Inlet Gas Separation

Slug Catchers

Filters

Filter Separators

Acid Gas Removal

Benfield

Amines (MEA, DEA, MDEA)

Selexol

Sulfinol

Ryan Holmes

Mol Sieve

Membranes

Sulfur Recovery

Claus Plants

Super Claus Plants

SCOT Tail-Gas Units

Strefford

LO-CAT

Dehydration

Glycol

Drizo

Molecular Sieve

NGL/LPG Extraction and Treating

Refrigerated Lean Oil Plants

Cryogenic (turbo-expander)

Caustic Scrubbing

Merox


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Section 1

Summary of Qualifications (cont.)

NGL Fractionation

Ethane Production

Ethane/Propane Production

Propane/Propylene Splitters

Iso/normal Butane Splitters

Isobutane Production (Engelhard and UOP)

Deisopentanizer

LNG

Import Terminals

Export Terminals

Liquefaction

Nitrogen Rejection and Cold Box Design

Compression

Reciprocating Machines

Centrifugal Machines

Screw Type Machines

Gas Plant Simulation Software Used by Aker Solutions

Software Use

HYSIM/HYSIS Entire gas plant simulation

Pro II (Simulation Sciences) Fractionation, expander plants, and dehydration

SPED (Bryan Research) Sulfur plant simulation

T-Sweet (Bryan Research) Amine plant simulation

AMSIM (DB Robinson) Amine plant simulation

Sulfur Recovery (Amoco) Design claus sulfur plant according to the Amoco technology


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Section 2

Gas Processing Capabilities

Aker Solutions has specialized in projects for the natural gas industry for over 40 years. Aker Solutions’ experience in gas processing work undertaken during recent years involves the whole range of engineering and management skills from conceptual design through to start-up and operation. Study work and FEED package preparation is often part of a large project where Aker Solutions has gone on to do EPC scope or continued as the client’s project manager. Gas Processing Plants

The gas treatment plant consists of several components that are typical of most plants. The design of these units is studied in some depth to create a flowsheet of the overall plant that meets the economic and technical optimization criteria imposed. Slugcatchers

Slugcatchers from small single vessels to large multi-finger units have been designed and built by Aker Solutions. The recent Conoco Syria unit was a multi-finger unit with a capacity of over 400 m3. The Conoco Theddlethorpe units were 800 & 1300 m3 (5,000 and 8,000 bbls) finger units, and the British Gas North Morecambe project has a large single vessel. The S. Pars design is for 4800 m3 (30,000 bbls) and the Taweelah gas plant slugcatcher is 10,000 m3 (60,000 bbls). Our past experience with various types and sizes of slugcatchers provides the depth of knowledge Aker Solutions has in the design and construction of this equipment. Gas and Liquid Separation

Gas and liquid separation using horizontal and vertical separators, with or without internals, are common components designed by Aker Solutions. For separators with proprietary designs of coalescing vanes or packs, specific equipment providers contribute to the design. Aker Solutions has developed certain proprietary technology in designing compact separators. Acid Gas Removal

The range of processes offered includes physical and chemical solvents. Aker Solutions has designed straightforward MEA and DEA units and under license proprietary units such as Benfield, MDEA, Sulfinol, Selexol, Ucargol and other activated MDEA depending on bulk removal or partial removal. Molecular sieves and membrane systems for special removal services have also been addressed. The Petronas project included an in-depth assessment of all the available processes followed by the evaluation of the selected process. (Refer to recent Acid Gas Removal projects at the end of this section.)


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Section 2

Gas Processing Capabilities (cont.) Gas Compression

Gas compressors with electric motor and gas turbines drivers like the RR RB211, GE Frame machines and LM2500’s is a common part of the evaluation of the processing plant. The evaluation of compression alternatives often includes the determination of onshore and offshore options in conjunction with the pipeline options. This aspect was considered recently on the Theddlethorpe, South Pars and Taweelah projects. Dehydration and Hydrate Suppression

The choice between dehydration using glycol, methanol, or molecular sieves is usually decided by the downstream processing requirements. Molecular sieves are normally utilized in cryogenic NGL/LPG Extraction plants where water concentration must be reduced to ppm levels. Aker Solutions can provide a wealth of experience in the selection of proper hydrate inhibition methods. NGL/LPG Extraction

Aker Solutions has substantial experience in all areas of gas processing operations including NGL/LPG Extraction from natural gas streams. Aker Solutions’ experience in NGL/LPG Extraction processes from natural gas streams includes refrigerated lean oil absorption plants, high pressure straight refrigeration units using external refrigeration, cryogenic J.T. expansion plants and cryogenic expander plants. Aker Solutions has developed different cryogenic processes for extraction of NGL/LPG from natural gas including very high ethane and propane plus recovery utilizing turboexpanders. NGL Fractionation

Aker Solutions has substantial experience in fractionation system design for separating ethane, propane, butanes and pentane plus products. The NGL fractionation systems designed by Aker Solutions are optimized for energy efficiency and capacity utilization. Our design experience includes new fractionation systems ranging from 20,000 barrels per day to over 100,000 barrels per day of inlet throughput. Aker Solutions has also worked on many capacity increases of the existing fractionation systems. Substantial increases in throughput have been achieved from upgrades of existing fractionations for Enron and TransCanada.

Our experience includes butane splitters with heat cycle for energy optimization. We have also designed the butamer units for converting n-butane to iso-butane and integrating the butamer unit with the main fractionators to achieve the overall fractionation system efficiency. In order to meet the final product specifications, product treating is required. Aker Solutions has experience with the removal of impurities like CO2, moisture, H2S, COS and mercaptans from the various products to meet the required specifications. These methods include caustic, non-regenerables, and scavenger processes, as well as regenerable processes like molesieve for final product treating.

Aker Solutions has achieved as much as 50% increase in the existing fractionation systems by carefully analyzing the existing units and making necessary modifications which saved substantial capital cost for the upgrade.


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Section 2

Gas Processing Capabilities (cont.)

LNG

Aker Solutions’ LNG experience has evolved from an impressive background in overall gas processing. Aker Solutions has specialized in projects for the natural gas industry for over 40 years. Our experience in gas processing work undertaken during recent years involves the whole range of engineering and management skills from conceptual design through to start-up and operation. Study work and FEED package preparation is often part of a large project where Solutions has gone on to do EPC scope or continued as the client’s project manager. Our experience includes import/export terminals and liquefaction facilities. We design all LNG facilities per NFPA 59A and all worldwide industry-accepted standards. Sour Service Equipment and Materials

Aker Solutions always considers materials selection for equipment and pipe to NACE requirements for sour service. For this type of study our specialists group can offer the necessary expertise to meet the requirements of the project.

Sulfur Recovery

Sulfur recovery in sour gas processing plants often requires the assessment of Claus type units and tail gas clean up. This has become more important now that there are tougher controls on flaring. Aker Solutions’ recent experience in sulfur recovery units (SRU) and tail gas treating units includes small units like 60 tons per day SRU units for Shell Offshore in Alabama with SCOT tail gas treating units. On the large scale units Aker Solutions is involved in design and construction of three (3) trains of 400 tons per day each SRU units with a single RESULT tail gas treating unit for SINCOR in Venezuela. Aker Solutions’ experience also includes the various enhancements of SRU including Superclause units. Additional tail gas treating experience not only includes the H2O based processes like SCOT and RESULT units, but also includes SO2 based and other processes like liquid redox. Utilities and Offsites

Utilities such as vent and flare facilities, steam, hot oil, fuel etc. have a significant contribution to the economics of a process and local conditions are always different with each plant. Offsite facilities such as tankage and run down lines require process definition. Aker Solutions is well positioned to provide needed assistance to our clients in helping with the utilities, infrastructure and logistics.

Aker Solutions has delivered substantial cost savings to our clients by offering dedicated teams to focus on delivering utilities and off-site project scopes to support larger capital programs.


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Section 2

Gas Processing Capabilities (cont.) Deep Ethane Recovery

Aker Solutions has developed different cryogenic processes for the extraction of ethane from natural gas including very high ethane and propane plus recovery utilizing turboexpanders. Aker Solutions has considerable experience in dealing with the design of the high ethane and propane plus recovery process utilizing new as well as existing gas plants. The technical and economic considerations for the process facilities to be incorporated into the existing gas plant are different from those relating to new installations. Aker Solutions has field-proven design for high ethane and propane plus recovery processes. These processes can have many variations depending on the ethane plus content of the gas and the inlet conditions. The general outline of most of Aker Solutions-developed processes for high ethane and propane plus recovery using turboexpanders is provided in the following text. The basic process involves the dehydration of the inlet high pressure gas using fixed bed molecular sieves to remove the water to less than 1 ppmv. The bone-dry gas is processed in brazed aluminum heat exchangers to cool the high pressure inlet gas with the low pressure methane-rich residue gas. Normally a complex heat exchanger train is used to conserve the cold refrigeration from the process to minimize the external refrigeration. This involves prefractionation steps in the demethanizer column to recover the coolant from the cold NGL liquids. The high pressure cold inlet gas is separated from the condensed liquids and is expanded using the turboexpander. The expander not only helps provide the cold refrigeration in the process to condense the ethane and heavier NGL liquids, but also recovers the useful work to compress the low pressure gas to minimize the compression horsepower. The cold fluids from the expander discharge and the high pressure separator liquids are fed to the demethanizer to remove the methane and lighter components from the ethane and/or propane and heavier NGL liquids.

Normally the demethanizer has a side reboiler and bottom reboiler integrated in the inlet gas heat exchanger train to recover the refrigeration and also reduce the external heating requirements. The low to medium pressure methane-rich cold residue gas is heat exchanged with the high pressure inlet gas as described above to recover the refrigeration. This residue gas is usually recompressed with the turboexpander-driven compressor. The residue gas is finally compressed to a pipeline pressure using additional compressors. In addition, the front-end facility may include H2S/CO2 removal and mercury removal depending on the level of these components present in the inlet gas and the recovery level for the ethane. Aker Solutions designed the high ethane recovery process using the turboexpander for Petronas in Malaysia, Enron in the U.S, and Santos Ltd. in South Australia. The processes for these locations have been proven in the field as designed.

Aker Solutions’ high ethane recovery processes utilize an internal or external reflux system to provide the cold lean reflux for the demethanizer. These processes provide high ethane recovery, higher energy efficiency and lower capital costs.


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Section 2

Gas Processing Capabilities (cont.) The high ethane recovery processes designed by Aker Solutions are one of the best in the industry. They are well proven processes. Our thermodynamic and physical property data in processes for light hydrocarbons are mature and proven over the last 15 years. It is important to recognize the thermodynamic behavior at high pressure and low cryogenic temperatures for the high ethane recovery processes. The coldest temperatures in the process vary from -140oF to -160oF. At these cold temperatures it is also important to understand the CO2 freezing characteristics. The feed gas pressure and composition also play a predominant role in the process design. Apart from feed gas compositions and conditions, the amount of impurities, the product specifications and the recovery level play an important role in the process selection. Our experience in the NGL and LPG extraction plants, especially in the high ethane or propane recovery processes from the natural gas using the turboexpander, is built around the ability to meet the challenges of the industry.


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Section 3

Gas Processing Technology The following text is a summary of Aker Solutions’ resources and capabilities in gas processing technology. Some of the proprietary and open-art technologies in gas processing that we have been involved in are described below. Additionally, Aker Solutions has excellent NGL/LPG fractionation expertise. Aker Solutions has also executed various projects in past utilizing third party proprietary process technology such as Ortloff in the NGL and LPG liquid extraction area. One of the recent projects completed for PETRONAS and PTT joint venture in Thailand where Aker Solutions engineered and managed construction utilized Ortloff OHR licensed process.

Proprietary and Open Art Technologies

The following description provides Aker Solutions’ experience in the gas processing, especially cryogenic liquids recovery (ethane and/or propane recovery) technologies: High Pressure Absorber

This design, developed by Aker Solutions, was utilized for the Statoil Kollsnes gas processing plant expansion. It is a cryogenic expander plant for NGL/LPG extraction. The process is energy efficient and allows utilization of a single train approach for inlet capacities over 1.4 BSCFD. The process can tolerate higher CO2 in the inlet gas feed as well as much lower overall compression power compared to many other technologies at present. The design configuration allows a larger capacity train while keeping the process energy efficient. Aker Solutions designed the plant, taking the availability and constructability of larger equipment into consideration. The selection of materials of construction for large vessels and columns was developed consistent with large vessels and columns constructability at higher design pressure and cryogenic temperatures. The plant also utilized large compressors for high pressure gas compression using variable speed electric motor drivers. Methane Recycle

This design was used in the PETRONAS Gas SDN BHD project. The process design for two trains, 700 MMSCFD each, was developed by Aker Solutions engineers to achieve very high ethane recovery combined with high demethanizer pressure to achieve significant tolerance to CO2 in the plant feed. The process design for this facility also included the flexibility to run in an ethane rejection mode with very high propane recovery, as well as minimum liquids recovery for dewpoint control only. Cold Separator Split

Similar to Ortloff’s GSP design, this process was developed by Aker Solutions (previously John Brown) in the early 1980’s and successfully installed in Santos Ltd’s Moomba Gas Plant in South Australia. This plant processed 900 MMSCFD of rich, high CO2 gas with an ethane recovery in excess of 80%.


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Section 3

Gas Processing Technology (cont.)

GSP

This design has been used in a number of Aker Solutions projects. In Enron’s Eunice Gas Processing plant, it served to improve ethane recovery, while in the Teesside Plant in the U.K. it was used for high propane recovery. This design has in the past been protected by a number of patents; however, most of these have expired.

Pre-rectifier

This is an expander process design for high propane recovery in which recoverable hydrocarbons are absorbed from the expanded feed gas using light hydrocarbons as absorption medium. Among others, Aker Solutions used this design in the ethane rejection mode of the PETRONAS Gas SDN BHD project listed above.

Refrigeration

Under certain circumstances, especially on upstream projects, Propane Refrigeration may be the most economical process. Aker Solutions has successfully executed many of these projects including the Shell Yellowhammer Plant. The revamp of TransCanada’s Eunice Gas Plant included debottlenecking of a 250 MMSCFD cryogenic liquids recovery plant that utilizes ethane refrigeration to generate demethanizer reflux. Aker Solutions has a long successful history of gas plant design and has built gas plants using a wide variety of liquid recovery processes. In addition to those listed above, these include Double-Expander, LSP, and Packed HP Separator. Most of these processes are no longer considered competitive or are applicable only in very specific circumstances. Aker Solutions also has extensive experience with Lean Oil Absorption plants. While in most new gas processing plants cryogenic designs have replaced lean oil absorption, in special circumstances absorption is still viable, and Aker Solutions has recently designed lean oil absorption plants. Furthermore, Aker Solutions has been involved in debottlenecking and the expansion of existing lean oil plants, some of which were originally built by Dresser Engineering, which became part of John Brown, a predecessor of today’s Aker Solutions. Grass roots Lean Oil Absorption Plant designs include: Lean Oil Absorption facility for Nasr Petroleum Company, Suez, Egypt (1997-1999). This

project is a vapor recovery unit in a hydrocracking complex. It recovers 85% of mixed LPGs from the hydrocracking unit’s off-gas.

Lean Oil Absorption facility for Statoil in a confidential location in the FSU. Aker Solutions performed conceptual and basic design as well as a TIC estimate. Capacity was 400 MMSCFD, with propane recovery of 70%.

Refrigerated Lean Oil Absorption facility (Khuff Gas Development Project, Abu Dhabi, UAE) for Abu Dhabi National Oil Company (ADNOC). Plant capacity is 540 MMSCFD. Butane recovery was 85%-95%, with a maximum propane content of 35%. Condensate vapor pressure was 8 psi maximum.


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Section 3

Gas Processing Technology (cont.) Debottlenecking and Front-End Projects include: Refrigerated Lean Oil Absorption Facility (Eunice Gas Plant, Louisiana) for TransCanada.

Capacity of the lean oil plant was approximately 400 MMSCFD. Aker Solutions’ scope included debottlenecking for additional throughput as well as optimization. The plant recovered 35%-40% of feed ethane and 90% propane.

Refrigerated Lean Oil Plant (Henry Gas Plant, Louisiana) for Texaco. This plant was originally built by Dresser Engineering. Aker Solutions performed process design work for Texaco including simulation of the lean oil plant. The plant has a capacity of 1,000 MMSCFD in two trains. It recovers 40% ethane and 93% propane.

Refrigerated Lean Oil Absorption Plant (Gregory Plant, Texas) for Enron. Aker Solutions developed the simulation model for this facility for troubleshooting and optimization. The plant recovered 85% propane with mild refrigeration (20°F).

Nitrogen Rejection Technology

Aker Solutions also had one patented cryogenic Nitrogen Rejection Technology; however, the patent will soon expire and there is no plan to renew or resubmit at this time. Aker Solutions personnel have executed some projects in this area using other proprietary and open art technologies.

Molecular Sieves

Aker Solutions designed numerous plants using molecular sieve in gas and liquids service. Plant capacities up to 1,500 MMSCFD were included. Our experience includes high and low pressure regeneration as well as with and without mercury removal. We are experienced in the design of molecular sieve units with 3A and 4A mole sieve for gas dehydration. We have design experience with specialized operations for reduction in COS formation. Some of our past design experience includes special design considerations during regeneration of molecular sieve beds in which small amount of sulfur and oxygen is present in the inlet feed gas.

TEG

Aker Solutions has carried out many designs involving TEG as a drying medium. Some projects included using stripping gas or proprietary process enhancements such as Cold Finger, which was used in BP’s Cupiagua project/Columbia and Amoco’s Bairoil CO2 Cycling plant. The Drizo process was considered for the design of the Enron Teeside facility and ARCO’s China offshore project.

Ethylene Glycol Injection

Aker Solutions has used this simple design to achieve dewpoint suppression in less demanding services. This method was used for ethane drying for the PETRONAS Gas SDN BHD project.


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Section 3

Gas Processing Technology (cont.)

Methanol Injection

This method of hydrate control has been used in several subsea pipeline projects. Aker Solutions’ design included methanol recovery, reconcentration, storage, and export to the offshore injection location. Projects include the 290 MMSCFD Caister/Murdoch onshore facility and the 210 MMSCFD Pickerill Gas Terminal (Conoco, U.K.). The following are mercury removal technologies with which Aker Solutions has experience. Mercury removal has been part of most of the cryogenic gas processing plant projects.

Mercury Removal

As part of feed pretreatment, it is necessary to remove mercury if present in the feed gas to avoid corrosion with brazed aluminum heat exchangers. Aker Solutions has designed many mercury removal systems (MRS) since 1990. Our experience with MRS includes the following: Sulfur impregnated activated carbon adsorbents Metal sulfide systems Metal sulfide/oxide systems

Most of our systems for MRS from natural gas are based on sulfur impregnated activated carbon absorbents. The liquid systems MRS are based on metal sulfide on alumina or carbon substrate or metal oxide/sulfide based systems. We evaluated gas and liquid phase regenerable molesieve (zeolite) systems for MRS, but in most cases these systems were not installed.

Experience Using Licensed Technologies

Aker Solutions’ experience with gas processing technologies is described in the previous section. To our knowledge the methane recycle process is not proprietary. GSP, LSP, and Double-Expander designs were patented by Ortloff Engineers, Ltd.; however, these patents have expired. It is possible that certain configurations of the pre-rectifier process may be covered by patents in some countries. The Lean Oil Absorption Processes are not proprietary. “Cold Finger” Technology is licensed by Gas Conditioners International Co. Drizo is licensed by OPC Drizo Inc. We utilized these technologies on BP’s Cupiagua and Enron’s Teesside projects, respectively.


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Section 4

Project Experience Section 4.1 Worldwide Project Locations Section 4.2 Onshore Oil & Gas Scope & Project Type Table Section 4.3 LPG/NGL/LNG Project Experience Section 4.4 Acid Gas Removal, Sulfur Recovery, and Tail Gas Treating Units Section 4.5 Compressors/Turbines and Compressor Station Experience Section 4.6 Select Coal Degasification Projects Section 4.7 Project Profiles


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Section 4

Project Experience (cont.) Section 4.1 Worldwide Project Locations j

EcuadorTechint/GaronConoco

North AmericaSempra Energy – LNGDistrigas – LNG Shell – YellowhammerEnron – 63 projectsTransCanadaPecten (Shell)PEMEXAmoco – 2 projectsAnardako – 2 projectsMarathonKochNorthwest PipelineBP Alaska GTLU.S. Dept of EnergyInternorthOxy – San MiguezPSI – 2 projectsReynolds – Mustang IslandSanta Fe – High IslandsSonat – Mustang IslandsTexas Eastman – High IslandsTransco – High IslandsUnion OilZachry – Quarters

ChileMethanex- 2 projectsSipetrol

AfricaMobil Nigeria - EDOP- UBITQIT I&IIChevron Angola- Sanha- Malongo- Block 14

Chevron- EGP3

Elf- IME-Edikan- OduduNNPC- Pipeline- DepotsSasol- Pipeline

VenezuelaPequivenSINCOR

ColombiaBP Colombia- Cuisiana- Cupiagua- Covenas

SyriaConocoAl Furat- 8 projects

ChinaPhillips- 24-1 - XijiangAmoco- LiuhuaARCO- Yacheng

Sakhalin IslandExxon Sakhalin I- Chayvo- OPF- Transportation

DubaiDubai Petroleum - 3 projects

Saudi ArabiaSaudi Aramco- Hawtah Field Develop- S. Area Plant Upgrade

IndiaEnron - LNGONGC - 23 projects

MalaysiaPetronas- 2 projects

KazakhstanOCL - 2 P/LORYX - FEED

IndonesiaP.T. Trans-PacificGulf OilMobil- BD Field

Africa (cont’d)Ranger Oil- Ivory Coast - platformBenin- Saga - topsides- Kerr McGee - deepwaterTexaco Angola- LNG Study- Pipeline- Offsites Study

ThailandPTT-Petronas

NorwayNorsk Hydro- Ormen LangeStatoil- Kollsnes

ItalyRasGas- Adriatic LNG

j

EcuadorTechint/GaronConoco

North AmericaSempra Energy – LNGDistrigas – LNG Shell – YellowhammerEnron – 63 projectsTransCanadaPecten (Shell)PEMEXAmoco – 2 projectsAnardako – 2 projectsMarathonKochNorthwest PipelineBP Alaska GTLU.S. Dept of EnergyInternorthOxy – San MiguezPSI – 2 projectsReynolds – Mustang IslandSanta Fe – High IslandsSonat – Mustang IslandsTexas Eastman – High IslandsTransco – High IslandsUnion OilZachry – Quarters

ChileMethanex- 2 projectsSipetrol

AfricaMobil Nigeria - EDOP- UBITQIT I&IIChevron Angola- Sanha- Malongo- Block 14

Chevron- EGP3

Elf- IME-Edikan- OduduNNPC- Pipeline- DepotsSasol- Pipeline

VenezuelaPequivenSINCOR

ColombiaBP Colombia- Cuisiana- Cupiagua- Covenas

SyriaConocoAl Furat- 8 projects

ChinaPhillips- 24-1 - XijiangAmoco- LiuhuaARCO- Yacheng

Sakhalin IslandExxon Sakhalin I- Chayvo- OPF- Transportation

DubaiDubai Petroleum - 3 projects

Saudi ArabiaSaudi Aramco- Hawtah Field Develop- S. Area Plant Upgrade

IndiaEnron - LNGONGC - 23 projects

MalaysiaPetronas- 2 projects

KazakhstanOCL - 2 P/LORYX - FEED

IndonesiaP.T. Trans-PacificGulf OilMobil- BD Field

Africa (cont’d)Ranger Oil- Ivory Coast - platformBenin- Saga - topsides- Kerr McGee - deepwaterTexaco Angola- LNG Study- Pipeline- Offsites Study

ThailandPTT-Petronas

NorwayNorsk Hydro- Ormen LangeStatoil- Kollsnes

ItalyRasGas- Adriatic LNG


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Section 4

Project Experience (cont.) Section 4.2 Onshore Oil & Gas Scope & Project Type Table

U.S. and Europe Onshore Oil & Gas Projects

Project Aker Solutions’ Activities

Contract Scope Plant

Client Plant Location

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GULF LNG LNG REGASIFICATION AND RECEIVING TERMINAL

PASCAGOULA, MS, USA

2011

BP CATS TERMINAL EMM FEDERAL CONTRACT

UK 2008

CONFIDENTIAL UNDERGROUND STORAGE

THE NETHERLANDS 2008

SEMPRA LNG LNG REGASIFICATION AND RECEIVING TERMINAL

HACKBERRY, LA, USA

2008

BP EMM WYTCH FARM PROJECT

UK 2007

NIGERIA LNG GAS TRANSMISSION SYSTEM 2/4 SLUG CATCHER

NIGERIA 2007

NORSK HYDRO ORMEN LANGE GAS PROCESSING PLANT

AUKRA, NORWAY 2007

COLUMBIA NATL. RESOURCES

ACID GAS REMOVAL WEST VIRGINIA, USA 2006

STATOIL/ GASSCO

KOLLSNES GAS PLANT EXPANSION

WEST COAST NORWAY

2006

HHI/ONGC MUT PIPELINE PROJECT

WEST COAST INDIA

2005

PTT–PETRONAS SONGKHLA GAS SEPARATION PLANT

SONGKHLA, THAILAND

2005

STATOIL VESTPROCESS MONGSTAD EXPANSION PROJECT

NORWAY 2004

BHGL/ONGC 3 PIPELINE PROJECT WEST COAST INDIA

2004

ENRON DABHOL LNG TERMINAL

INDIA 2002

CAIRN ENERGY INDIA LTD

ONSHORE GAS FACILITY

INDIA 2001


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Section 4



Project Aker Solutions Activities



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ARAMCO SOUTHERN AREA PLANTS UPGRADE

SAUDI ARABIA 2001

BP D250 GAS-TO-LIQUIDS ALASKA 2001

CONOCO INTEGRATED DEZ GAS PROJECT

SYRIA 2001

DISTRIGAS LNG REVAPORIZATION MASSACHUSETTS, USA

2001

SINCOR SULFUR COMPLEX JOSE, VENEZUELA 2001

CHEVRON MALONGO TERMINAL GAS PLANT

ANGOLA 2000

CHEVRON SANHA CONDENSATE RECOVERY

ANGOLA 2000

ADCO OILFIELD FACILITIES BU HASA, ABU DHABI 1998

ADNOC KHUFF – ONSHORE/ OFFSHORE GAS FAC.

ABU DHABI 1998

CONOCO THEDDLETHORPE SITE ALLIANCE SUPPORT

THEDDLETHORPE, UK

1998

ESSO NATUNA ONSHORE/ OFFSHORE

INDONESIA 1998

INTERCONNECTOR GAS TERMINAL BACTON AND ZEEBRUGGE

1998

PETRONAS NATURAL GAS PROCESSING PLANT

MALAYSIA 1998

SANTOS LTD. BALLERA GAS CENTRE SW QUEENSLAND AUSTRALIA

1998

TRANSCANADA NGL PLANT LOUISIANA, USA 1998

BP AMOCO DF OFFGAS PROJECT WASTE GAS TIMT

HULL, UK

PEDEC ONSHORE/OFFSHORE FACILITIES

IRAN 1997


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BP AMOCO GAS OPRN & MAINT SUPPORT OF GAS TERMINAL

TEESIDE, UK 1996

BP COLOMBIA CUPIAGUA FIELD COLOMBIA 1996

CONOCO CSM FACILITIES UPGRADE

THEDDLETHORPE, UK

1996

ARAMCO CENTRAL ARABIA DEV. PROGRAM

HAWTAH FIELD, SAUDI ARABIA

1995

TRANSCANADA NGL PLANT LOUISIANA, USA 1995

BP GAS TERMINAL DEWPOINT CONTROL

DIMLINGTON, UK 1994

CONOCO PICKERILL COMPRESSION

THEDDLETHORPE, UK

1994

ENRON LPG PLANT TEXAS, USA 1994

THAPPLINE MULTI-PRODUCTS PIPELINE

THAILAND 1994

BP KINNEIL OIL & GAS PROCESSING

UK 1993

AL FURAT OMAR OIL RECOVERY FACILITIES

SYRIA 1993

CONOCO CAISTER MURDOCH GAS TERMINAL

THEDDLETHORPE, UK

1993

TRANSCANADA LPG PLANT LOUISIANA, USA 1993

BP MILLER GAS RECEPTION

PETERHEAD, UK 1992

CONOCO PICKERILL GAS TERMINAL

THEDDLETHORPE, UK

1992

SAGASCO BEHARRA SPRINGS GAS PLANT

WESTERN AUSTRALIA

1992

CQNG DENISON TROUGH GAS PROJECT

QUEENSLAND, AUSTRALIA

1991


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PETROFINA REFINED PROD PIPELINE

HUMBER-HERTS, UK 1991

SHELL YELLOWHAMMER GAS PLANT

ALABAMA, USA 1991

TEXACO LPG PLANT OKLAHOMA, USA 1991

AL FURAT OMAR N / SHAHEL GAS GATHERING

SYRIA 1990

OSOCO SHUKEIR GAMMA GOSP EGYPT 1990

TEXACO NGL PLANT OKLAHOMA, USA 1990

STEG GAS TREATMENT/ COMPRESSION PLANT

EL BORMA, TUNISIA 1989

CONOCO VIKING GAS TERMINAL THEDDLETHORPE, UK

1988

YPF GAS TREATMENT PLANT

LATA OIL FIELD, ARGENTINA

1988

PETROLAND GAS TREATMENT HARLINGTON, NETHERLANDS

1987

SHELL GAS TERMINAL EXPANSION

ST. FERGUS, UK 1986

S.C.O.P. OIL EXPORT PIPELINE SYSTEM

IRAQ 1985

BRITISH GAS GAS TERMINAL MORECAMBE BAY, UK

1984

BRITISH GAS GAS TERMINAL MORECAMBE BAY, UK

1984

SANTOS LTD. COOPER BASIN LIQUIDS PROJECT

MOOMBA, SOUTH AUSTRALIA

1984

SHELL GAS TERMINAL MOSSMORRAN, UK 1984

BP KINNEIL GAS TREATING PLANT

GRANGEMOUTH, UK 1983


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BRITISH GAS COMPRESSION STATION

AYLESBURY, UK 1983

BP GAS TERMINAL PROCESS UNITS

SULLOM VOE, UK 1982

CHEVRON OIL REFINERY EXPANSION

PERTH AMBOY, NJ USA

1982

CITIES SERVICES NGL FRACTIONATION MONT BELVIEU, TX USA

1982

EXXON OFFGAS COMPRESSION

BATON ROUGE, LA USA

1981

SONATRACH GAS, LPG & COND PIPELINES

ALRAR/ARZEW, ALGERIA

1980

TECHMASH- IMPORT

ETHYLENE PIPELINES (2)

USSR 1980

MOBIL GAS & NGL PLANTS ST. FERGUS/ NIGG BAY UK

1979

EXXON DEBUTANIZER BATON ROUGE, LA USA

1978

BASRAH PETROLEUM

OIL EXPORT EXPANSION

RUMAILA, IRAQ 1977

ESSO C4 STORAGE FAWLEY, UK 1977

SONATRACH COMPRESSION STATIONS (2)

SKIKDA, ALGERIA 1976

BP DALMENY OIL TERMINAL

FIRTH OF FORTH, UK 1975

BRITISH GAS COMPRESSION STATION

CAMBRIDGE, UK 1975

SONATRACH LPG TREATING PLANT ARZEW, ALGERIA 1973

MICHIGAN GAS UNDERGROUND GAS STORAGE

MICHIGAN USA

SOUTHERN CALIFORNIA GAS

UNDERGROUND GAS STORAGE

HONOR RANCHO, CALIF., USA


20

Section 4

Project Experience (cont.) Section 4.3 LPG/NGL/LNG Project Experience The following list includes LPG/NGL/LNG projects:

Aker Solutions’ LNG/LPG/NGL Projects

Client Location Description CapacityMM SCFD Scope

TIC $MM Product

Year Comp.

Gulf LNG Pascagoula, MS USA

LNG Receiving & Regasification Terminal

1,500 Permitting, FEED, EPC

Conf LNG 2011

Ingleside Energy Center LLC

Ingleside, Texas USA

LNG Receiving & Regasification 1,000 Pre-FEED, EPC (On

Hold)

665 LNG/LPG/NGL

2011

Sempra Energy Cameron, Louisiana, USA

LNG Regasification and Receiving Terminal

1,500 EPC 700 LNG 2008

ExxonMobil/QP Offshore Italy GBS LNG Regasification Facility 750 FEED/EPCM

900 LNG 2007

Norsk Hydro Aukra, Norway Ormen Lange Onshore Gas Processing Plant

2,400 FEED/EPCMA

2,000 NGL/LPG 2007

Columbia Natl. Resources

West Virginia, USA Acid Gas Removal Unit 1,500GPM EPCM Conf Acid Gas Removal

2006

Statoil/GASSCO West Coast Norway Kollsnes Gas Plant Expansion 1,400 E --- LPG 2006

ChevronTexaco Gulf of Mexico & Offshore Baja, California

Port Pelican & Baja GBS LNG Facilities

2000/750 FEED 1,000 LNG 2006

Linde AG (Statoil) Melkøya, Norway Snohvit LNG Plant 540 EPCS 100 LNG 2005

PTT-PETRONAS Gas

Thailand Gas Separation Plant 425 PMC/FEED 250 LPG 2005

Freeport McMoRan

Gulf of Mexico LNG Regasification Facility/Energy Hub

PreFEED/CE/

Permit Support

Conf LNG/LPG/NGL

2004

ExxonMobil Gulf of Mexico GBS LNG Import Terminal 1,250 S/CE Conf LNG 2003

Shell Offshore Northeast USA

GBS LNG Regasification Facility 1,000 S/CE Conf LNG 2003

Enron* India Dabhol LNG Receiving Terminal --- EC 250 LNG 2002

Aramco Services Co.

Saudi Arabia Southern Area Gas Plants Upgrade

800 FEED 128 NGL 2001

CMS Equatorial Guinea LNG Liquifaction Production Facility

4MM TPA S/CE NA LNG/LPG 2001

Conoco Syria Deir Ez Zor, Syria Integrated DEZ Gas Project 500 FEED/EPC 180 LPG 2001

Distrigas Everett, Massachusetts, USA

LNG Revaporization Expansion 600 FEED/EP 125 LNG 2001

Dynegy Hackberry, Louisiana, USA

LNG Import Terminal 750 S/CE NA LNG 2001

Texaco/Sonangol Angola Onshore Liquefaction Facilities (PRICO Technology)

800 Pre-FEED Conf LNG/LPG 2001

Chevron Overseas Petroleum

Offshore Angola, West Africa

Sanha Secondary Recovery Condensate/ Development Project

600 FEED/E 1,500 LPG 2000


21

Section 4

Project Experience (cont.) Section 4.3 LPG/NGL/LNG Project Experience

Aker Solutions’ LNG/LPG/NGL Projects

Client Location Description CapacityMM SCFD Scope

TIC $MM Product

Year Comp.

Shell Kollsnes, Norway Gas Processing & Commissioning Plant

1300 FEED/EPC 512 NGL/LPG 1996

Gazprom/Yamal Russia LNG Export Terminal S NA LNG 1995

TransCanada Gas Processing (Enron)

Geismar, Louisiana, USA

Riverside Fractionation Plant Debottlenecking

28,000 BPD

FEED/E/SU 4 NGL 1995

Enron Agua Dulce, Texas, USA

Magnolia City Gas Plant Expansion

60 FEED/EC/SU

NA NGL 1994

TransCanada Cameron, Louisiana, USA

Sabine Pass Gas Plant 200 FEED/ECM/SU

.5 NGL 1993

Enron Argentina EASA Gas Processing Facility 750 FEED NA NGL 1992

Enron Teesside, UK Teesside Gas Processing Plant 600 FEED 40 LPG 1991

Shell Offshore, Inc.

Mobile Bay, Alabama, USA

Yellowhammer Gas Plant 200 PM/EPCM 70 NGL 1991

Texaco Erath, Louisiana, USA

Henry Gas Plant 1,000 SIM/E NA NGL 1991

British Gas Tunisia Miskar Gas Plant 250 S/CE 350 **CGP NRU

1990

Texaco USA Maysville NGL Plant --- EPC NA NGL 1990

YPF Argentina Gas Treatment Plants 1 & 2 --- E NA NGL 1990 SCOPE * The Houston office provided

engineering support to our UK office

E = Engineering SU = Start-up ** CGP – Cryogenic Gas Plant

P = Procurement PM = Project Management NRU – Nitrogen Rejection Unit

C = Construction SIM = Simulation NGL – Natural Gas Liquid

PMC = Program Management Contractor S = Study LPG – Liquified Petroleum Gas

CM = Construction Management CE = Cost Estimate LNG – Liquified Natural Gas

CMA = Construction Management Assistance

NA = Not Available


22

Section 4

Project Experience (cont.) Section 4.4 Acid Gas Removal, Sulfur Recovery, and Tail Gas Treating Units Aker Solutions’ experience in acid gas removal, CO2 and H2S handling, transportation and safety systems design is an accumulation of many years of experience in conceptual process development, front end engineering design and development of facilities which includes Pre-FEED and FEED studies, detailed engineering, construction of the facilities including modularization concepts where economically attractive in this specific area. Aker Solutions’ experience, as indicated in the following table, includes acid gas removal from the facilities design in natural gas production (both offshore and onshore). Our experience also includes the gas clean-up from refineries and synthesis gas production in which similar facilities are required. The experience in this area includes a wide range of applications in which the inlet gas contains over 65% CO2 with small amounts of H2S to less than 1% or less CO2 with higher amounts of H2S. As you will note from the experience table, the application in acid gas removal systems involve different types of solvent systems that includes primary, secondary and tertiary amine systems, formulated amines for bulk CO2 or selective H2S removal and physical solvents involving selexol, methanol, etc. In addition, we have also been involved in bulk CO2 removal using membranes, cryogenic processes and a few H2S scavenger and fixed-bed processes such as molecular sieve. The examples are noted in the table as an indication of our involvement in this specific area over the last 30 years. In many of these applications, the starting point has been in the front end conceptual process development in which the process selection and optimization has been the key part of our experience internally as well as working with appropriate vendors of formulated solvents and membrane (where applicable) in achieving the desired outcome for the process selection. The acid gas removal or clean-up applications in natural gas treatment has mainly involved the following purposes or objectives: Removal of CO2 and H2S to meet natural gas pipeline specifications Removal of CO2 and H2S to meet cryogenic gas plant for natural gas liquids (NGL)

extraction as well as process constrains to avoid CO2 freeze-up. Removal of CO2 to a low ppm levels to meet liquefied natural gas (LNG) plant process

constraints, again for the CO2 freeze-up concern. Removal of CO2 and H2S from ethane product to meet petrochemical feed stock

specification requirements where catalyst poisoning has been a concern Removal of CO2 to a very low ppm levels depending on the specification for downstream

chemical production such as Ammonia synthesis. Again, the following table reflects our broad-based experience and know-how which helps us optimize the new as well as existing plant applications in which the upgrades are necessary for increased throughput volumes or changes in the inlet gas conditions.


23

Section 4

Project Experience (cont.) Section 4.4 Acid Gas Removal, Sulfur Recovery, and Tail Gas Treating Units

Aker Solutions’ Acid Gas Removal, Sulfur Recovery and Tail Gas Treating Experience

Year Client/Project Solvent

Type Aker Solutions’ Scope

2009 ExxonMobil – Natuna Gas Field Development, Offshore, Indonesia. Inlet gas volume 2400 MMSCFD, 65% CO2 and 0.5% H2S, multiple trains

Cryogenic Process

Technology comparison, front end process development, layout, cost estimate

2009 Baard Energy, CO2 compression and injection for EOR application

N/A Technology comparison, cost estimate, life cycle cost analysis

2009 Bharat Oman Refinery (BORL) Project, Madhya Pradesh, India 2 x 90 MTPD Sulfur Recovery Units (SRU) (1 x 330 TPH Amine Regeneration Unit (ARU)

Selexol EP

2008 Statoil Claus Unit for Sulfur Recovery for SMIL Project, Mongstad, Norway

AMDEA Basic Engineering & EPC

2008 Max Petroleum, Astrakhanskiya Field, Kazakhstan. Initial gas production 150 MMSCFD, later year 600 MMSCFD with 20% H2S and 10% CO2 in the sour gas. High reinjection pressure

Activated MDEA based

solvent comparison

Feasibility and conceptual study, cost estimate

2008 SES/Consol Northern Appalachia Fuel Project, Benwood, West Virginia. Synthesis gas containing 25% CO2 and 1.3% H2S, Acid Gas removal (2000 gpm circulation), sulfur plant – approx. 150 TPD, single train with tail gas treatment unit

Selexol Feasibility study

2007 Chennai Petroleum Corp. Ltd., Chennai, India. 2 trains (45.5 & 35 TP) sour water stripper units (SWS)

N/A FEED

2007 American Lignite Energy (ALE) CTL Project, North Dakota. Synthesis gas containing 32% CO2 and 0.3% H2S. Acid gas removal (11000 gpm solvent circulation) and sulfur plant (3X50%) trains with single train tail gas treating unit. Sulfur production approx. 200 TPD

Rectisol (Methanol)

Feasibility, Pre-FEED design and cost estimate support

2007 Faustina Hydrogen Products, Louisiana. Synthesis gas containing 40% CO2 and 1.4% H2S. Acid gas removal (5500 gpm solvent circulation) and third party sulfur plant (2 X 220 LTPD) with a single tail gas treating unit

Selexol FEED design, cost estimate support

2006 Indorama Ammonia Plant – Damietta, Egypt. Feed gas containing 17% CO2 and no H2S.

GAS/SPEC CS-Plus

Plant relocation, engineering and CM

2006 Columbia Natural Resources, West Virginia, Acid gas removal from High (25%) CO2 field. 1500 gpm circulation, revamp of existing unit

Selexol Conceptual, detailed engineering, procurement assistance, construction management


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2006 Siirtec Nigi/Sulphur Recovery Unit at MOL Oil and Gas Plc., Hungary. 90 tons/day unit

MDEA Detailed engineering and procurement assistance

2006 Duke Energy Gas Transmission, Canada, Kwoen Acid Gas Plant, acid gas plant expansion

Morphysorb Engineering design, procurement assistance and construction support

2005 QNI Syngas, Queensland, Australia. Synthesis gas containing 15% CO2 and no H2S

Benfield Existing plant revamp – process and equipment re-rated with new process conditions

2002 Westcoast Energy Inc., Canada, Kwoen Gas Plant, Sour gas processing facility designed to remove 28MMSCFD of acid gas from a stream of 300MMSCFD

Selexol Design, procurement, fabrication and field construction

2002 Chennai Petroleum Corporation Ltd., India, Sulphur Recovery Unit


2001 SINCOR Sulfur Complex, Venezuela, refinery gas treating, two identical trains. Solvent circulation rate: 2200 gpm each (DEA). Also one train of 1850 gpm (MDEA) for tail gas clean-up. Three trains of 400 tons/day each Claus sulfur plant.

DEA/MDEA Detailed engineering, procurement and construction

2000 Westcoast Gas Services, Inc., Jedney II Gas Processing Plant, 78MMSCFD Gas Sweetening (800 USGPM amine)

Ucarsol LE-703

Design, procurement, fabrication, field construction

2000 Elf Exploration and production,Lacq Field, Southern France, Inlet volume 3.5 MM Sm3/day, 22% H2S, 11.5% CO2, field redevelopment

Cryogenic and Membrane

Process

Technology comparison, front end engineering study, cost estimate

2000 BP Refining, Australia, revamp of Sulfur Recovery and Amine Unit to increase capacity of unit from 25t/d to 35 t/d and improve efficiency of unit

MDEA Front end engineering, process design and program management

1999 Kochi Refineries Ltd., Sulphur Recovery Unit at Kochi, India. 2 trains of 72 tons/day units


1999 BP/BOP Pox unit, Australia, Syngas Treating for CO2 Removal, Solvent circulation rate: 280 gpm

BASF Activated

MDEA

Basic engineering package, detailed engineering, construction management

1997 TransCanada (formerly Enron) Eunice Plant, Louisiana, ethane product treating for high CO2 and traces of H2S removal. Solvent circulation rate: 250 gpm

Ucarsol Basic, detailed engineering, procurement, CM support, plant operator’s training, start-up support


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1996 Texas Eastman, Texas, treating of 15 MMSCFD of syngas for CO2. Solvent circulation rate: 500 gpm

MEA Basic, detailed engineering, start-up support

1995 TransCanada (formerly Enron) Riverside Plant, Louisiana, ethane product treating for high CO2 removal with traces of H2S removal. Revamp of existing 250 gpm amine treating unit (conversion from MEA to Ucarsol) and installation of new 125 gpm Ucarsol unit

Ucarsol Conceptual, basic and detailed engineering, procurement, start-up assistance

1994 Petronas Gas Bhd., Malaysia. Natural gas treating containing high CO2 and traces of H2S removal. Solvent circulation rate: 19,000 gpm

BASF Activated

MDEA

Conceptual studies, process optimization cost estimate, technical support for detailed engineering and start-up


26

Section 4

Project Experience (cont.) Section 4.5 Compressors/Turbines and Compressor Station Experience Aker Solutions has engineered many compressor systems for services including hydrocarbons involving natural gas, process and synthesis gas as well as various refrigerant and air compressors, ranging in size from under 100 hp to over 65,000 hp. These installations involved reciprocating, centrifugal, hyper, screw and liquid ring compressors with various types of drivers, including gas fired turbines, gas and diesel engines, electric motors and steam turbines. Our experience in design of reciprocating compressors includes units with up to five stages as well as centrifugal units with multiple process stages. The following table provides details of our compressor and driver design and installations. A majority of our compressor station experience comes from onshore and offshore oil & gas installations. Our compressor station experience includes natural gas compression at various locations in the oil & gas production, gathering, processing and pipeline transportation process. Aker Solutions’ recent experience includes the design of six (6) compressor stations for Conoco Dez Gas in Syria. The design involved multiple compressor stations located in the field at the gas gathering stations. The compressor stations were designed and placed at appropriate locations. The gas is separated from the inlet condensate, compressed to a pipeline pressure using multistage, positive displacement reciprocating compressors. The condensate separated at low and medium pressure levels is pumped to pipeline pressure. The condensate, in most cases, was combined with high pressure gas for transportation to a central gas processing plant using a multi-phase pipeline. The condensed water is separated in the three phase separators at various stages and the pressure level was combined and then pumped for re-injection. The compressor stations were designed with maximum modularization using skid mounted separation and pumping equipment, packaged reciprocating compressors with drivers, coolers and other associated equipment. A separate system was designed to provide fuel gas treatment. A majority of the interconnecting piping was prefabricated for easy installation in the field. All of the compressor stations were self-contained with required utilities and other facilities such as air, pig launchers/receivers and metering, as well as compressor auxiliaries such as lube oil. Aker Solutions also designed pipeline compressor stations for the pipeline gas transportation of the Conoco Dez Gas Syria project. Here the dry lean gas from the central gas processing facility was compressed for pipeline transportation to the sales gas pipeline as well as excess gas for re-injection. The pipeline compressors in this case were centrifugal compressors with turbine drivers. Multiple compressors were required to provide the overall compression duty. The export gas pipeline compressor stations were part of the central gas processing facility. In addition to the above project, Aker Solutions’ experience also includes the design of compressor stations for the Norsk Hydro Orman Lange project in Norway. This facility, as part of the large onshore gas processing complex, utilized large compressors for transportation of the dry gas export pipeline from northwest of the Norwegian continental shelf to the UK, a 1200 km 42” long pipeline.


27

Section 4

Project Experience (cont.) Section 4.5 Compressors/Turbines and Compressor Station Experience The compressors were driven by one of the largest electrical motor drivers with 40 MW motors each. Aker Solutions has faced many similar challenges in the past in designing the compressor stations where the pipeline pressure has ranged from 600# ANSI systems to 1500# ANSI systems. Aker Solutions has also designed various compression systems to 6600 psig discharge pressure level where the gas is re-injected. In addition, Aker Solutions experience also includes pipeline booster stations where the compressor stations are designed to provide a pressure boost with low compression ratio at high pipeline pressure located along the export gas pipeline. Most of these compressor stations involved centrifugal compressors with turbine or electric motor drivers to provide pressure boost in the export gas pipeline. Our experience includes both offshore and onshore pipeline boosting stations. Most of these stations are highly automated and self- supported with all of the utilities and required compressor and turbine auxiliaries with the system design for high reliability. A recent example is the Exxon Mobile Sable project in Canada where the large Dresser Rand compressor with RB211turbine driver was utilized. In many of the compressor stations, especially in the gas gathering and wellhead level field locations, modularization is a key design consideration. In summary, Aker Solutions’ experience includes engineering, procurement and installation of many different types of compressor systems including various types of compressor stations for natural gas processing. Again, the following list provides examples of our compressors and drivers design, as well as our experience in the design of compressor stations.


28

Section 4

Project Experience (cont.) Section 4.5 Compressors/Turbines and Compressor Station Experience

Gas Compression Projects

Client Plant Location Completion Services Performed

Gulf LNG Energy

Pascagoula, Mississippi

In Progress EPC service for liquefied natural gas (LNG) receiving terminal including two LNG storage tanks and a regasification facility consists of three 1,400 hp IHI boil off gas compressors. Also includes one 2,000 hp Ariel pipeline compressor, and two 200 hp Atlas Copco vapor return blowers.

Exxon Mobil Offshore, Porto Viro, Italy

In Progress EPC service for offshore concrete liquefied natural gas terminal and regasification facility consists of two trains of 750 hp Dresser-Rand cryogenic boil off gas compressors.

Sempra LNG Cameron, Louisiana 2009 EPC services for liquefied natural gas receipt terminal and associated facilities consists of three 600 hp Burckhardt cryogenic boil off gas compressors, one 1,200 hp Ariel pipeline compressor and two 200 hp Atlas Copco vapor return blowers.

Exxon Mobil Sable Island, Canada 2004 Design for Gas Compression Platform Topsides consists of one 35,000 hp, 6 stage centrifugal, Dresser-Rand export gas pipeline compressor, driven by a Rolls Royce RB-211 turbine driver.

Chevron Overseas Petroleum Company

Offshore Block 0, Angola, West Africa Sanha Project

2004 Detailed engineering services for offshore oil and gas production with LPG extraction plant consists of four 30,000 plus hp each Dresser Rand reinjection compressors driven by RB-211 turbine drivers and compressing the gas to 6,600 psig pressure. Also includes two trains of 16,000 hp Dresser Rand separation compressors driven by solar Titan turbines compressing associated gas. The makeup gas compressors consists of three solar turbines (2 Mars and 1 Taurus) ranging in hp from 6,000 to 13,000 hp. The platform also includes smaller stabilizer overhead compressors.

Pemex Exploration & Production

Offshore Mexico, Canteral Field

2003 Detailed engineering for offshore production and compression platform consists of vapor recovery and six 12,000 hp Nuovo Pignone booster compressors with turbine drivers, compressing the gas to pipeline pressure for delivery to onshore.


29

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Conoco Syria Dez Gas Ltd.

Syria 2001 EPC services for infield gas gathering with compressor stations and an onshore gas processing facility. Detailed engineering and construction for total of six multi-stage centrifugal compressors with Nuovo Pignone PGP10B gas turbine drivers site rated at 11,000 hp each for residue and gas reinjection services. The maximum discharge pressure for gas reinjection is 5,000 psig. Also includes seven reciprocating single and multi-stage Aeriel compressors, sizes ranging from 250 hp to 4,100 hp electric motor driven with some variable frequency motors for natural gas services including gas gathering and pipeline. The facility also includes three multi-stage centrifugal propane compressors, 2,000 hp each for refrigeration service.


Offshore Angola Block 14, West Africa

2000 Engineering for offshore production facility includes gas compression studies and selection of gas compressors for produced and associated gas for reinjection and gas lift. The selection includes solar Mars turbine-driven multi-stage centrifugal compressors with discharge.


Onshore Angola – Malongo Terminal, West Africa

2000 Engineering for onshore low pressure gas gathering and compression for LPG recovery and gas conditioning plant. Three solar Saturn turbines with centrifugal compressors for multi-stage high MW natural gas.


Offshore Angola Block 0 – Sanha, West Africa

2000 FEED engineering for offshore gas gathering including one 16,000 hp and four 34,000 hp gas turbine-driven centrifugal compressors for gas compression to 6,600 psig.

Methanex Corporation, Chile

Punta Arenas, Chile 1999 EPC for multi-stage, centrifugal barrel type Dresser Rand syngas compressor, 41,700 hp, Mitsubishi multi-stage multi-valve passout/condensing steam turbine driver.

TransCanada Gas Processing

Eunice, Louisiana 1998 EPC plant revamp including installation of 1,000 hp engine-driven reciprocating compressor. Also modernized the overall control system for the multiple (5) solar compressors and turbines.

BP Exploration & Production

Cupiagua, Columbia 1997 EPC for crude oil gathering and gas reinjection facility including two GE Frame 5, 28,000 hp gas turbine-driven Nuovo Pignone centrifugal compressors for reinjection to 6,600 psig.


30

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Methanex Corporation, Chile

Punta Arenas, Chile 1996 EPC for multi-stage, centrifugal barrel type Dresser Rand syngas compressor, 41,700 hp, Mitsubishi multi-stage multi-valve passout/ condensing steam turbine driver.

BP Exploration & Production

Cupiagua, Columbia 1996 EPC for crude oil gathering and gas reinjection facility including one GE Frame 6, 32,000 hp gas turbine-driven Nuovo Pignone centrifugal compressor for reinjection to 6,600 psig.

Mobil Nigeria 1996 EP services for offshore gas compression platform including GE 25,000 hp gas turbine driven centrifugal compressor for reinjection to 3,000 psig.

Sterling Chemicals

Texas City, Texas 1996 EPC for replacement of an existing Dresser-Rand multi-stage compressor, 16,300 hp and upgrade of the multi-stage backpressure steam turbine.

Amoco Chemical Texas City, Texas 1995 One 3-stage, centrifugal compressor, one 3-stage Demag HVK-10 centrifugal compressor in tandem with one Demag VK-50 4-stage centrifugal compressor. Both compressors driven by an existing 15,000 hp synchronous motor.

Miles (Bayer) Baytown, Texas 1995 Two Demag VK80-Z, 2-stage, centrifugal integrally geared compressors with 7,500 hp each synchronous motor driver.

TransCanada Gas Processing

Riverside, Louisiana 1995 Plant revamp including two 800 hp and one 1,000 hp engine-driven reciprocating compressor

Coastal Chemicals

Cheyenne, Wyoming 1993 EPC for one Delaval multi-stage, barrel type compressor with 4,500 hp induction motor driver and speed increasing gearbox.

ARCO Oil & Gas Company

Wilburton, Oklahoma 1992 Definition and detailed engineering of four 1,000 hp Ariel JGK compressors.

ARCO Oil & Gas Company

Denver City, Texas 1992 Engineering services for two 4,000 hp I-R electric drive compressors.

El Paso Natural Gas Company

Arizona, New Mexico and Colorado

1992 Lump sum turnkey construction to add solar Centaur turbines and other modifications at four existing compressor stations.

Texaco E&P Inc. Andrews County, Texas

1992 EP services for one 3,000 hp Cooper Pennsylvania process and one 1,500 hp Cooper Superior reciprocating compressor.

Trident NGL, Inc.

Canton, Texas 1992 Detailed design, engineering and construction management for 3,110 hp reciprocating 2-stage gas pipeline compressors.


31

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Trident NGL, Inc.

Myrtle Springs, Texas

1992 Engineering services for two 1,440 hp Cooper-Bessemer GMVC-8C reciprocating compressors.

Northwest Pipeline Company

Utah, New Mexico, Washington

1991 Process engineering, detailed engineering and procurement to add solar Centaur turbines at five compressor stations.

Amoco Production Company

Durango, Colorado 1990 Engineering and construction of 205 MMSCFD natural gas processing plant. Includes five 5,000 hp motor driven field compressors and two 5,000 hp motor driven residue boosters.

El Paso Natural Gas

Durango, Colorado 1990 Engineering and construction of a natural gas parallel residue compression station. Includes one 5,000 hp motor driven residue compressor.

Shell Offshore Mobile, Alabama 1990 Process design, detailed engineering, procurement and construction of a 200 million SCFD natural gas plant to process raw and sour gas from offshore wells for pipeline distribution.


32

Section 4

Project Experience (cont.) Section 4.6 Select Coal Degasification Projects

El Paso Natural Gas Company Florida River Coal Degasification Project Florida River, Colorado Scope of work:..........................EPC Contract value: .........................USD 10 million General description: This facility was part of the coal degasification (coal bed methane production) project involving 220 MMSCFD peak capacity compression facilities where the low pressure gas was boosted in pressure to deliver the gas to the pipeline. The facility includes total installed compression of 15,000 HP and other miscellaneous small water treatment. Amoco Production Company San Juan Basin Coal Degasification Project San Juan, Colorado Scope of work:..........................EPC Contract value: .........................USD 63 million General description: The overall scope of work includes the following: Coal degasification facility gathering system The processing facility with peak capacity – 220 MMSCFD DEA gas treating unit for CO2 separation TEG dehydration Field gas compression from low pressure to pipeline delivery pressure with total

installed compression of 20,000 HP Water treating and other miscellaneous facilities


33

Section 4

Project Experience (cont.) Section 4.7 Project Profiles Conoco Syria Dez Gas Ltd. Integrated Dez Gas Project Deir Ez Zor, Syria

Description: This 450 MM SCFD grass roots facility included gas gathering, pipelines, compression, gas processing, offices and living quarters. Specific details of this scope include:

Inlet gas compression and cooling Gas gathering pipeline system Gas compressor stations (6) Inlet condensate separation and transportation to pipeline Dry gas chilling, condensate separation Fractionation of mixed LPG product Propane, butane and C5+ condensate Butane storage Export pipeline (± 250 KM of 18” .375 wt) Truck loading facility Lean residue gas recompression for gas reinjection High and low pressure flare systems Hot oil, cooling water and other utility system Low level propane refrigeration system requiring propane compression from

near atmospheric pressure Scope of Work: Engineering, procurement, construction, and precommissioning. Duration: Bid, Concept Development & FEED (Technip): 9 months Engineering Start: February 1999 Finish: January 2001 Construction Start: April 1999 Construction Completion: September 2001

Manhours: Approximately 400,000 engineering/design manhours

Mumbai: 250,000 manhours detailed design Houston: 80,000 manhours including coordination & support

Syria: 55,000 manhours buildings, pipeline systems TIC: $430 million TIC. Aker Solutions’ portion was U.S. $180 million.

Safety: Total construction manhours exceeded 4 million. Project achieved over 3 million manhours without LTI.


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Project Experience (cont.) Section 4.7 Project Profiles Norsk Hydro Ormen Lange Onshore Gas Processing Plant Aukra, Northwest Coast of Norway Description: The Ormen Lange Gas Field is located 120 kilometres northwest of Kristiansund.

It is being developed with subsea production facilities in 800-1100 metres water depth hooked up to the onshore sales gas processing and export plant at Aukra. The Ormen Lange development also involves the most extensive gas export pipeline system form the Norwegian continental shelve to the UK, a 1200 km long 42” pipeline. The installation also includes cavern storage for condensate and export by tanker.

Technical Data: Gas export capacity: 70 M Sm3/d Possibility for future upgrade to 80 M Sm3/d without major shutdown Condensate storage: 150,000 m3 Scope of Work: Performance of FEED, detailed engineering and follow-up engineering,

procurement, and construction management assistance for the gas plant. Main interface contractor for overall system responsible for the total Ormen Lange

project including subsea facilities, community power from national grid, and transport to consumers in the UK and Europe.

Project Value: Contract value of onshore gas processing plant is NOK 950 million. Total TIC of

project is NOK 66 billion. TIC of onshore facilities is NOK 16 billion. Award: March 2003 Production Start: October 2007 Status: Operational


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Project Experience (cont.) Section 4.7 Project Profiles Saudi Aramco Southern Area Gas Plants Description: The Maintain Gas Compression Capacity Project provided for the installation of

Compression Train B at Abqaiq Plant 499. The primary purpose of this project was to provide a reliable, efficient and safe gas compression system at the Abqaiq Plants, which have sufficient capacity to process the low pressure gases in a manner that complies with current environmental regulations. This project also allowed the retirement of old inefficient fired steam boilers and provided for efficient generation of high pressure steam with the installation of heat recovery steam generations (HRSGs), as well as diversification of the flare system to reduce the risk of business interruption through the strategic location of existing flare equipment and correction of deficiencies in the standby flare. This project also allowed for the retirement of Plant 332, which was approximately 35 years old. Machine units in this plant were no longer being manufactured and the equipment became unreliable with low efficiency.

The Abqaiq Plants had eight gas compression trains to compress gasses that have been removed in the spheroids and stabilization process at the Abqaiq Plants and in Intermediate Pressure (IP) and Low Pressure (LP) traps at Abqaiq GOSPs 5 and 6. The compressed gas and the NGL liquids recovered in the compression process are shipped to downstream facilities for treating and sales product separation. Under a previously completed project, a new compression train with a design capacity of 100 MMSCFD and NGL stripper facilities were installed in Plant 499 Train A commissioned in 1999. This compression train allows Abqaiq Plants to process offgas from Shaybah crude stabilization and to retire the old NGL Plant 337 commissioned in 1965. This facility consists of a gas compression train having two compression stages that are operated in tandem and driven by a common CGT driver. The new NGL stripper installed with Train A has spare capacity to handle future expansion in Plant 499 that will be installed under this project (Plant 499 Train B).


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Project Experience (cont.) Section 4.7 Project Profiles

The boilers at the Abqaiq Plants were also aging, and some existing boilers were in need of major repairs. The Master Plan for Abqaiq Plants is the recommendation that heat recovery projects be implemented to reduce the need for replacing these boilers. Heat recovery projects include the installation of heat recovery steam generators, which will use the waste heat from the exhaust of the combustion gas turbine drivers to provide additional high-pressure steam. Heat recovery steam generation units were also installed on the existing Train A as well as the proposed Train B being installed under this project.

Additionally, a second plant flare system, sized for a capacity of 700MM SCPD was designed for the project. Support facilities required for the Compression Train B included a new electrical substation as well as a team building and operator shelter.

Numerous engineering studies were conducted in conjunction with the preliminary design effort. They included electrical studies for load flow, short circuit and motor starting analysis and protective device coordination, operability and maintainability studies for the combustion gas turbine and flare installations, constructability studies for all facilities, a team building risk assessment and a motor control center load list, an environmental assessment of the Train B facilities as well as the new flare system, and a preliminary process hazards analysis of both facilities.

Duration: Conceptual work was awarded in July 2000 under a reimbursable General Services Agreement with Aramco Services Company. Conceptual engineering for the gas compression train and flare system was completed March 2001. The LSTK project detail design, procurement and construction was awarded to others in July 2001 with completion expected in 2003.

Scope of Work: Conceptual design, optimization studies, preliminary engineering, and detailed FEED package of the total project and detail design of the 69kV substation. Conceptual work consisted of generating the following deliverables: Generate Definitive Scope of Work and EPC Schedules Generate Project Proposal Books Perform the ER Estimate for the Total Installed Costs of the Project Generate the LSTK Contract Bid Packages

HO Manhours: 37,000 manhours Project Value: TIC: $128 million


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PETRONAS Gas Sdn. Bhd. Gas Processing Plants 5 & 6 Terengganu, Peninsular Malaysia

Description: Cryogenic expander plant & NGL fractionation. 1,000 MMSCFD net sales gas, approximately 1400 MMSCFD inlet gas. The grass roots facility includes two cryogenic expander units. Each unit has a capacity of 700 MMSCFD. The plant extracts over 90% ethane and over 99% of propane and heavier components from the inlet gas using Aker Solutions’ developed high ethane recovery process. In addition to the cryogenic expander plant, the design also includes the following:

Acid Gas (CO2) removal using BASF activated MDEA process Mercury removal from the inlet gas stream Molecular sieve dehydration NGL treating Inlet condensate stabilization Two NGL fractionation trains, 100,000 BPD capacity each Ethane, propane, butanes and gasoline separation Refrigerated and pressurized storage for different products Environmental and utilities design

Scope of Work: Program Management Consultant (PMC) scope including design basis

development, conceptual design, basic engineering package, EPC bid evaluation support, detail engineering supervision at contractor’s office on behalf of client and technical support during construction and commissioning.

Manhours: 100,000 engineering/design manhours Value: Estimated installed cost of

the project is U.S. $800 million. Aker Solutions’ services value at $8 million.


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Project Experience (cont.) Section 4.7 Project Profiles Shell Offshore Inc. Yellowhammer Gas Plant Mobile, Alabama Description: Refrigerated NGL recovery plant, sour gas treating and sulfur plant with capacity

of 200 MMSCFD. This 200 MMSCFD facility consisted of sour gas treating unit to remove H2S using sulfinol solvent, Claus sulfur recovery unit and a SCOT tail gas unit. The facility also included a refrigerated NGL recovery unit and an NGL treating unit to produce approximately 2500 BPD of NGL, produced water stripping, gas turbine electric cogeneration unit, waste heat boilers, product storage and truck loading facilities.

Scope of Work: Project management, detailed engineering, procurement and construction

management. Manhours: 220,000 manhours Value: Estimated installed cost for the project was U.S. $70 million.


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Project Experience (cont.) Section 4.7 Project Profiles TransCanada Gas Processing Inc. Eunice Gas Processing Plant Expansion Eunice, Louisiana Description: Lean oil and two cryogenic expander plants with NGL fractionation facility. Plant

capacity of 1050 MMSCFD. The existing plant expansion included basic engineering of the existing refrigerated lean oil extraction plant, two cryogenic expander plants, one of which was designed for 95% ethane recovery from the inlet gas and NGL fractionation facility. The process study also included the UCARSOL treating unit evaluation for CO2 removal from the ethane product, existing equipment evaluations, additional equipment requirements to meet future change in feed stock with increased throughput of 100 MMSCFD, new two phase pipeline hydraulics and cost estimate for additional equipment to eliminate the plant bottlenecks. Gas plant revamp detailed engineering for the work included: Fractionation column revamp for capacity increase Refrigeration system (propane) expansion Steam system revamp Cooling tower addition Amine Unit addition Propane treater addition Various vessels, exchangers and pumps addition for capacity expansion Plant flare and thermal oxidizer debottleneck Complete modernization of the plant and advanced control implementation

Scope of Work: Design basis development, basic engineering, detailed engineering, procurement

and start-up support. Manhours: 125,000 engineering/design manhours Value: Estimated installed cost of the project was U.S. $40 million. Aker Solutions’

services value U.S. $8 million.

Eunice Gas Plant with High Pressure Demethanizer


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Project Experience (cont.) Section 4.7 Project Profiles TransCanada Gas Processing Inc. Riverside Fractionation Plant Debottlenecking Geismar, Louisiana

Description: NGL fractionation facility with plant capacity of 28,000 BPD demethanized liquid. The scope of work included the debottlenecking of the existing fractionation facility which included the deethanizer, depropanizer, debutanizer, and iso-normal butane splitter columns. The plant throughput was increased from approximately 15,000 BPD of lower ethane containing feed to 28,000 BPD of higher ethane and much higher CO2 containing demethanized liquids. Aker Solutions also provided the advanced control configuration and optimization for four distillation columns which reduced the energy consumption (Btu/gallon) of the fractionation facility by 20%. Debottlenecking of the facility also included revamping the existing amine treating (UCARSOL) unit and addition of new parallel unit to remove the CO2 from ethane product.

Scope of Work: Design basis development, basic engineering package, detailed engineering and

plant start-up support. Manhours: 12,000 engineering/design manhours Value: Estimated installed cost of the project was U.S. $4 million


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Project Experience (cont.) Section 4.7 Project Profiles TransCanada Gas Processing Inc. Sabine Pass Gas Plant Cameron, Louisiana Description: Cryogenic expander plant with plant capacity of 200 MMSCFD. The scope of

work included the debottlenecking of the existing cryogenic expander plant for CO2 freeze-up problems in the demethanizer due to the increased CO2 in the inlet feed. Aker Solutions developed the process to achieve the solution to the problem for this existing plant without the addition of an amine unit to remove the CO2 from the inlet gas. The solution was achieved by addition of minimum equipment, piping and instrumentation within the cryogenic plant and saved substantial capital cost compared to the solutions under consideration.

Scope of Work: Design basis development, basic engineering package, detailed engineering,

construction management and plant start-up support Manhours: 3,000 manhours Value: Estimated cost U.S. $0.5 million.


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YPF Gas Treatment Plant I and II Nequen Province, Argentina Description: Refrigerated gas plant which included two straight refrigerated NGL recovery

plants. The facility included inlet gas cooling using the cold lean gas and external propane refrigeration, gas dehydration with ethylene glycol injection, condensate stabilization and hot oil heating system for all the process heating requirements. The stabilized NGL product was delivered to a high pressure pipeline. The low pressure gas from the stabilizer was compressed to a high pressure and sent to the gas pipeline.

Scope of Work: Process design, detail engineering support to Tauro engineering in Argentina and

start-up assistance. Manhours: 7,000 manhours

Natural Gas Processing - 2010

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