Air PTI Application - Department of Environmental · PDF file3/8/2013 . PTI Application Form...

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Transmittal

Ms. Mary Ann Dolehanty Michigan Department of Environmental Quality Air Quality Division - Permit Section Constitution Hall, 3

rd Floor North

525 West Allegan Street Lansing, MI 48933-1502

March 8, 2013

Re: Permit to Install (PTI) Application

Air Quality Control System Retrofit Presque Isle Power Plant (SRN B4261) We Energies 2701 North Lakeshore Boulevard Marquette, Michigan

Project No. G120697

For Review and Approval For Your Use As Requested Sent By: Jacquelyn F. Linck, P.E.

COPIES DATE DESCRIPTION 4 1 1

3/8/2013 3/8/2013 3/8/2013

PTI Application Form (original and three copies) PTI Application Support Documentation CD with electronic version of PTI Application

COMMENTS A second copy of the PTI Application has been sent directly to the MDEQ-AQD District Office as follows: Mr. Ed Lancaster Upper Peninsula District Office 420 Fifth Street Gwinn, MI 49841-3004 If you have any questions or require additional information, please contact me at 616-464-3736 or [email protected].

tc By Hand Delivery and e-mail cc/att: Mr. Ed Lancaster - MDEQ- AQD (By FedEx and e-mail)

Mr. Les Kowalski - We Energies (By FedEx and e-mail) Mr. Robert A. Greco, P.E. - We Energies (By e-mail only) Ms. Sharon Cameli - We Energies (By FedEx and e-mail - 2 copies) Mr. Brian L. Warner, CHMM - Wolverine Power (By FedEx and e-mail) Mr. Clay Raasch, P.E. - Trinity Consultants (By e-mail only) Mr. Tom Ghesquiere, P.E. - HDR (By e-mail only)

mailto:[email protected]�

MICHIGAN DEPARTMENT OF ENVIRONMENTAL QUALITY - AIR QUALITY DIVISION

DEi.\. PERMIT TO INSTALL APPLICATION FOR oea USE ONLY APPLICATION NUMBER

For authority to install, construct, reconstruct, relocate, or modify process, fuel-burning or refuse burning equipment and/or control equipment. Permits to install are required by administrative rules pursuant to Section 5505 of 1994 PA 451, as amended.

Please type or print clearly. The "Application Instructions" and "Information Required for an Administratively Complete Permit to Install Application" are available on the Air Quality Division (AQD) Permit Web Page at http://www.deq .state.mi.us/aps. Please call the AQD at 517-373-7023 if you have not been contacted within 15 days of your application submittal.

1. FACILITY CODES: State Registration Number (SRN) and North American Industry Classification System (NAICS)

SRN I B I 4 I 2 I 6 I 1 I NAICS I 2 I 2 I 1 1 I 1 I 2 I 2. APPLICANT NAME: (Business License Name of Corporation, Partnership, Individual Owner, Government Agency)

Presque Isle Power Plant

3. APPLICANT ADDRESS: (Number and Street) MAIL CODE:

2701 N. Lakeshore Blvd.

CITY: (City, Village or TownShip) I STATE' ZIP CODE: COUNTY:

Marquette MI 49855 Marquette

4. EQUIPMENT OR PROCESS LOCATION (Number and Street - if different than Item 3)

CITY: (City, Village or Township) ZIP CODE: COUNTY:

5. GENERAL NATURE OF BUSINESS:

Electric Generation

6. EQUIPMENT OR PROCESS DESCRIPTION: (A Description MUST Be Provided Here. Include Emission Unit IDs. Attacl1 addilional sheets if necessary; number and date each page of the submittal.)

Five existing pulverized coal-fired steam electr i c generating units, identified as EUBOILER5, EUBOILER6, EUBOILER7, EUBOILER8 and EUBOILER9, will b e retrofitted with control technology capable of reducing ni t rogen oxides, sulfur ox i des, and hazardous air pollutants (HAPs) regulated under 40 CFR Part 63, Subpart UUUUU.

Pleas e see the enclosed documentation for a detailed description of the project.

7. REASON FOR APPLICATION: (Check all that apply.)

I2J INSTALLATION I CONSTRUCTION OF NEW EQUIPMENT OR PROCESS (MATERIAL HANDLING)

I2J RECONSTRUCTION I MODIFICATION I RELOCATION OF EXISTING EQUIPMENT OR PROCESS - OATE INSTALLED: 1974 to 1979 o OTHER - DESCRIBE REVISE THE SHORT·TERM EMISSION RATES FOR EACH COMPRESSOR ENGINE

8. IF THE EQUIPMENT OR PROCESS THAT WILL BE COVERED BY THIS PERMIT TO INSTALL (PTI) IS CURRENTLY COVERED BY ANY ACTIVE PERMITS, LIST THE PTI NUMBER(S): NA

9. DOES THIS FACILITY HAVE AN EXISTING RENEWABLE OPERATING PERMIT (ROP)? D NOT APPLICABLE D PENDING APPLICATION I2J YES

PENDING APPLICATION OR ROP NUMBER: MI - ROP- B4 2 61-2 0 07b 10. AUTHORIZED EMPLOYEE: TITLE: PHONE NUMBER: (Include Area

Leslie D. Kowalski Asset Manage r Code)

906-226-5757

SIGNATURE:~ JJ . .~~ . .1d2- DATE; ?j~ -I} E-MAIL ADDRESS:

:) Sj /3 Les . Kowalski@we-enera:i .... . com

11. CONTACT: (If dlfferen! than Authorized Employee. The person to contact with questions regarding this application) PHONE NUMBER: (Include Area

Robe rt A. Greco, P.E. Code)

414-221-5441 CONTACT AFFILIATION: E-MAIL ADDRESS: We Energies bob.greco@we- e nergies.com

12. IS THE CONTACT PERSON AUTHORIZED TO NEGOTIATE THE TERMS AND CONDITIONS OF THE PERMIT TO INSTALL? I2J YES DNO

fOR DEQ USE ONLY - DO NOT WRlTE.BELOW DATE OF RECEIPT OF ALL INFORMATION REQUIRED BY RULE 203:

DATE PERMIT TO INSTALL APPROVED: SIGNATURE:

DATE APPLICATION I PTI VOIDED: SIGNATURE:

DATE APPLICATION DENIED: SIGNATURE:

A PERMIT CERTIFlCAtE WILL BE ISSUED UPO.N APPROVAL OF A PERMIT TO INSTALL

EQP 5615E (Rev. 09/2006)

Permit to Install Application Air Quality Control System Retrofit

Presque Isle Power Plant 2701 North Lakeshore Boulevard

Marquette, Michigan

Prepared for: Wisconsin Electric Power Company

d/b/a We Energies

March 8, 2013 Project No. G120697

Fishbeck, Thompson, Carr & Huber, Inc. Engineers • Scientists • Architects • Constructors 1515 Arboretum Drive, SE, Grand Rapids, MI 49546 Telephone: 616-575-3824

PERMIT TO INSTALL APPLICATION

AIR QUALITY CONTROL SYSTEM RETROFIT

PRESQUE ISLE POWER PLANT

2701 NORTH LAKESHORE BOULEVARD

MARQUETTE, MICHIGAN

PREPARED FOR:

WISCONSIN ELECTRIC POWER COMPANY

d/b/a

WE ENERGIES

PROJECT NO. G120697

MARCH 8, 2013

TABLE OF CONTENTS

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1.0 EXECUTIVE SUMMARY.................................................................................................................... 1

2.0 PROCESS OVERVIEW ..................................................................................................................... 2 2.1 Existing Power Plant Description ............................................................................................ 2 2.2 Description of Proposed Project .............................................................................................. 2

2.2.1 Boosted Over Fire Air and Low NOx Burners for NOx Control (EUSGUs 5 through 9) .................................................................................................................... 3

2.2.2 SDA Systems for SO2 and Acid Gas Control (EUSGUs 5, 6, and 7) ......................... 3 2.2.3 DSI Systems for SO2 and Acid Gas Control (EUSGUs 8 and 9) ................................ 3 2.2.4 PAC for Mercury Control (EUSGUs 5 through 9) ....................................................... 4 2.2.5 Fabric Filters (EUSGUs 5 through 9) .......................................................................... 4 2.2.6 Balance of New Plant Equipment Associated with the Proposed Modification .......... 4

3.0 REGULATORY REVIEW ................................................................................................................... 6 3.1 Michigan Regulations .............................................................................................................. 6

3.1.1 Air Pollution Control Rule 201 – Permit to Install Requirements ................................ 6 3.1.2 Air Pollution Control Rules 224 to 230 – T-BACT Requirement for New and

Modified Sources of Air Toxics and Health-Based Screening Level Requirement for New or Modified Sources of Air Toxics.................................................................. 6 3.1.2.1 Air Pollution Control Rule 224 – T-BACT Requirement for New and

Modified Source of Air Toxics; Exemptions ................................................... 7 3.1.2.2 Air Pollution Control Rule 225 – Predicted Maximum Impacts of TACs ........ 7

3.1.3 Air Pollution Control Rule 301 – Standards for Density of Emissions ........................ 7 3.1.4 Air Pollution Control Rule 331 – Emission of Particulate Matter ................................ 8 3.1.5 Air Pollution Control Rule 401 – Emission of Sulfur Dioxide from Power Plants ........ 8 3.1.6 Air Pollution Control Rule 801 – Emission of Oxides of Nitrogen From Non-SIP

Call Sources ................................................................................................................ 8 3.1.7 Air Pollution Control Rule 901 – Nuisance Odors and Dust ....................................... 8 3.1.8 Mercury Emission Limitations ..................................................................................... 9 3.1.9 Michigan’s Part 18 Rules – PSD ................................................................................. 9

3.2 Federal Regulations ................................................................................................................ 9 3.2.1 NAAQS – Attainment Status Considerations ............................................................ 10 3.2.2 40 CFR 60 Subparts D, Da – NSPS ......................................................................... 10

3.2.2.2 NSPS Reconstruction Analysis .................................................................... 11 3.2.3 40 CFR 60 Subparts OOO– NSPS ........................................................................... 12 3.2.4 National Emission Standards for Hazardous Air Pollutants (NESHAPs) ................. 13

3.2.4.1 40 CFR 63 Subpart UUUUU - NESHAP ...................................................... 13 3.2.5 Federal Acid Rain Program 40 CFR Parts 72 through 76 ........................................ 13 3.2.6 Federal CAIR ............................................................................................................ 13

4.0 EMISSION CHARACTERISTICS ..................................................................................................... 14 4.1 Applicability Determination for PSD ...................................................................................... 14

4.1.1 Baseline Actual Emissions ........................................................................................ 15 4.1.2 Projected Actual Emissions ...................................................................................... 16 4.1.3 Excluded Emissions .................................................................................................. 17 4.1.4 Projected Emissions Increase .................................................................................. 18

4.2 Ancillary Particulate Source Emissions ................................................................................. 18 4.2.1 Paved Road Emissions ............................................................................................. 18 4.2.2 Material Handling Emissions .................................................................................... 19

4.3 TAC and HAP Emissions ...................................................................................................... 20

5.0 CARBON MONOXIDE PSD BACT ANALYSIS ............................................................................... 21 5.1 General Top-Down PSD BACT Process ............................................................................... 21 5.2 Other Considerations for Determining BACT ........................................................................ 23

5.2.1 Demonstrated in Practice ......................................................................................... 23

TABLE OF CONTENTS

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5.2.2 Applicable NSPS and NESHAPs .............................................................................. 23 5.2.3 Previous BACT/LAER Determinations ...................................................................... 23

5.3 Carbon Monoxide Top-Down BACT Analysis ....................................................................... 24 5.3.1 EUSGUs 5 and 6 Analysis ........................................................................................ 25 5.3.2 EUSGU 7 Analysis .................................................................................................... 28 5.3.3 EUSGUs 8 and 9 Analysis ........................................................................................ 31

6.0 AIR QUALITY MODELING AND AIR TOXIC EVALUATION ........................................................... 35 6.1 Model Input Parameters ........................................................................................................ 36

6.1.1 Model Selection ........................................................................................................ 36 6.1.2 GEP Stack Height Analysis ...................................................................................... 36 6.1.3 Terrain Data .............................................................................................................. 37 6.1.4 Receptor Grids .......................................................................................................... 37 6.1.5 Meteorological Data .................................................................................................. 37 6.1.6 Building Parameters .................................................................................................. 37 6.1.7 Source Parameters ................................................................................................... 38

6.1.7.1 Point Source Parameters ............................................................................. 38 6.1.7.2 Volume Source Parameters ......................................................................... 38

6.1.8 Short-Term Emission Rates ...................................................................................... 39 6.1.8.1 Past Actual Short-Term Emission Rates...................................................... 39 6.1.8.2 Future Potential Short-Term Emission Rates .............................................. 40

6.2 Modeling Analysis for Short-Term PM10, PM2.5, SO2, and NOx ............................................. 40 6.2.1 Significant Impact Analysis and Results ................................................................... 41 6.2.2 NAAQS Analysis - NOX ............................................................................................. 41

6.3 PSD Modeling Analysis for Carbon Monoxide ...................................................................... 42 6.3.1 Significant Impact Analysis and Results ................................................................... 42 6.3.2 PSD Class I Increments ............................................................................................ 43

6.4 TAC Modeling ........................................................................................................................ 43 6.4.1 TAC Emission Rates and Results ............................................................................. 43

7.0 SUMMARY AND CONCLUSION ..................................................................................................... 45 LIST OF FIGURES Figure 1 Location Map Figure 2 Preliminary Site Arrangement (Provided by HDR) Figure 3a Units 5-6 AQCS Retrofit Bituminous Coal Flow Diagram (Provided by HDR) Figure 3b Units 5-6 AQCS Retrofit PRB Coal Flow Diagram (Provided by HDR) Figure 4 AQCS Flow Diagram for EUSGU 7 (Provided by HDR) Figure 5 AQCS Flow Diagram for EUSGUs 8 and 9 (Provided by HDR) LIST OF TABLES Table 1 Summary of New and Existing Emission Units Table 2 NSR Pollutant Baseline Emissions for Project Table 3 Past Actual to Projected Actual Analysis Table 4 Estimated Maximum Short-Term Pollutant Emissions of Boilers 5 and 6 Table 5 Estimated Maximum Short-Term Pollutant Emissions of Boiler 7 Table 6 Estimated Maximum Short-Term Pollutant Emissions of Boilers 8 and 9 Table 7 Total HAP Emissions for Project Table 8 Model Input Parameters – Point Sources Table 9 Model Input Parameters – Volume Sources Table 10 SIL Model Results Summary Table 11 CO Startup/Shutdown SIL Model Results Summary Table 12 NAAQS Model Results Summary Table 13 Unitized TAC Model Results

TABLE OF CONTENTS

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Table 14 PAH Relative Potency Table 15 Dioxin Furan Relative Potency Table 16 Maximum Potential Ambient Impacts LIST OF APPENDICES Appendix 1 Draft ROP Appendix 2 Presque Isle Capacity Statement (Provided by HDR Michigan, Inc.) Appendix 3 Baseline Data Appendix 4 Projected Utilization Appendix 5 Projected Annual Actual Emissions for Project Appendix 6 Ancillary Particulate Source Data Appendix 7 Summary of USEPA RBLC Database Appendix 8 BACT Analysis Cost Information Appendix 9 CD Containing Modeling-Related Files Appendix 10 Building Parameter Modeling Inputs Appendix 11 Model Input Parameters – Truck Traffic Calculations Appendix 12 Past Actual Hourly Emission Rates Appendix 13 MDEQ Additional Source Data Appendix 14 Additional Existing PIPP NOX Source Parameters LIST OF ABBREVIATIONS/ACRONYMS AERMOD American Meteorological Society/Environmental Protection Agency Regulatory Model AQCS Air Quality Control Systems AQD Air Quality Division BACT Best Available Control Technology BPIP-Prime Building Profile Input Program-Prime CAA Clean Air Act CAIR Clean Air Interstate Rule CFR Code of Federal Regulations CEM Continuous Emissions Monitoring CO carbon monoxide CO2 carbon dioxide CO2e equivalent carbon dioxide CPM condensable PM CT combustion turbine dscfm dry standard cubic feet per minute DSI dry sorbent injection EGU electric generating unit ESP electrostatic precipitator EUSGU electric utility steam generating unit FTC&H Fishbeck, Thompson, Carr & Huber, Inc. GEP Good Engineering Practice GHG greenhouse gas (es) g/m2 grams per square meter gr/dscf grains per standard cubic feet H2SO4 sulfuric acid HAP Hazardous Air Pollutant HCl hydrogen chloride HF hydrogen fluoride Hg mercury IRSL Initial Risk Screening Level ISCST3 Industrial Source Complex-Short Term ITSL Initial Threshold Screening Level LAER Lowest Achievable Emission Rate

TABLE OF CONTENTS

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lb/hr pound per hour lb/lb-mole pounds per pound mole lb/MMBtu pounds per million British thermal units lb/ton pounds per ton lb/VMT pounds per vehicle mile traveled MACT Maximum Achievable Control Technology MAERS Michigan Air Emissions Reporting System MATS Mercury Air Toxics Standards MDEQ Michigan Department of Environmental Quality MMBtu/hr million British thermal units per hour MWe megawatt of electrical generation output MWh megawatts of electrical generation produced in an hour NAAQS National Ambient Air Quality Standards NED National Elevation Dataset NESHAP National Emission Standards for Hazardous Air Pollutants N2O nitrous oxide NO2 nitrogen dioxide NOX nitrogen oxides NSPS New Source Performance Standards NSR New Source Review O2 Oxygen PAC powder activated carbon PAI Predicted Ambient Impacts Pb lead metal PM Particulate Matter measured using Method 5 from 40 CFR 60 Appendix A PM2.5 Fine Particulate Matter equal to or less than 2.5 microns PM10 Fine Particulate Matter equal to or less than 10 microns PSD Prevention of Significant Deterioration RACT Reasonably Available Control Technology RBLC RACT/BACT/LAER Clearinghouse (USEPA) ROP Renewable Operating Permit scf standard cubic feet SDA spray dryer absorber SIP state implementation plan SO2 sulfur dioxide SO3 sulfur trioxide TAC Toxic Air Contaminant T-BACT Best Available Control Technology for Toxics tph tons per hour tpy tons per year µg/m³ micrograms per cubic meter USEPA U.S. Environmental Protection Agency USGS U.S. Geological Survey VOC volatile organic compound We Energies Wisconsin Electric Power Company d/b/a as We Energies

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1.0 EXECUTIVE SUMMARY Fishbeck, Thompson, Carr & Huber, Inc. (FTC&H) has prepared this Air Use Permit to Install application on behalf of Wisconsin Electric Power Company d/b/a as We Energies (We Energies) for a proposed installation of air quality control systems (AQCS) that are capable of reducing nitrogen oxides (NOX), sulfur dioxide (SO2) and hazardous air pollutants (HAPs) regulated under 40 CFR Part 63, Subpart UUUUU (EGU Mercury and Air Toxics Standards [MATS] Rule) from existing electric utility steam generating units (EUSGUs) 5, 6, 7, 8, and 9 at the Presque Isle Power Plant (PIPP) located at 2701 North Lakeshore Boulevard, Marquette, Michigan. Refer to Figure 1 for Location Map. The existing State Registration Number for this facility is B4261. This document contains the information required to evaluate this application including a description of the existing plant, proposed AQCS, operating schedule, emission estimates, a Prevention of Significant Deterioration (PSD) analysis for carbon monoxide (CO), a hybrid analysis demonstrating the project will not be subject to PSD for all other regulated New Source Review (NSR) pollutants, and an air toxics demonstration. EUSGUs 5 and 6 are capable of firing both bituminous and sub-bituminous coal, while EUSGUs 7, 8, and 9 are capable of firing sub-bituminous coal. This application has been prepared such that all current fuel options have been accounted for and remain unchanged. Using the 2011 Michigan Air Emissions Reporting System (MAERS) reportable emissions as a reference point, the AQCS project has the potential to reduce facility-wide actual emissions by the following percentages for NOx and SO2 in addition to facilitating compliance with the EGU MATS Rule: Potential Reduction of NOx and SO2

Pollutant 2011 emissions

(tons/year) Controlled Emissions with

AQCS (tons/year) Potential

Reduction Nitrogen Oxides 5056 2528 50% Sulfur Dioxide 7978 2061 74%

We Energies is proposing best available control technology (BACT) emission limits for CO which is the only pollutant subject to PSD for this AQCS project. The dispersion modeling demonstrates that at the proposed CO BACT limit, the project is below the CO significant impact level. Proposed Emission Limit

Pollutant BACT Limit (lb/MMBtu) Averaging Time

Carbon Monoxide Current Proposed 30 boiler operating

day rolling average None 0.20


2.0 PROCESS OVERVIEW 2.1 EXISTING POWER PLANT DESCRIPTION PIPP is a pulverized coal-fired electric utility steam generating plant. EUSGUs 5 and 6 are capable of firing both bituminous and sub-bituminous coal, while EUSGUs 7, 8, and 9 are capable of firing sub-bituminous coal. All EUSGUs have fuel oil fired startup guns for heating each EUSGU to the point where coal firing can commence. Fuel oil firing is not used for operating each EUSGU on a normal basis; however, it is occasionally used for boiler flame stabilization. The plant currently does not have the capability to use natural gas fuel. The plant is currently operating pursuant to Renewable Operating Permit (ROP) No. MI-ROP-B4261-2007b. A draft ROP renewal recently issued for public comment is included in Appendix 1 and describes existing emission units. 2.2 DESCRIPTION OF PROPOSED PROJECT The proposed AQCS equipment for NOX consists of individual boosted over fire air systems on each of the five EUSGUs and new Low NOX burners on EUSGUs 5 and 6. SO2 and HAP acid gas control will be accomplished via installation of three spray dryer absorbers (SDAs) on EUSGUs 5, 6, and 7, and Dry Sorbent Injection (DSI) systems on EUSGUs 8 and 9. Powder activated carbon (PAC) injection for mercury (Hg) control is currently installed and used on EUSGUs 7, 8, and 9 and will be added to EUSGUs 5 and 6. The existing fabric filters and booster fans currently associated with retired EUSGUs 1 through 4 will be reused for particulate and non-volatile metal removal following the EUSGUs 5 and 6 SDAs. The balance of new plant equipment required for the project includes one lime storage and slurry preparation facility, one DSI storage silo, one PAC storage silo, a new ash collection system for the existing EUSGUs 7 through 9 fabric filter, which will control EUSGUs 8 and 9, and new redundant auxiliary transformers to feed the AQCS equipment. The existing CEMS will be reconfigured and a mercury CEMS will also be added. None of the proposed work for the AQCS will result in an increase in capacity for any EUSGU. A detailed explanation regarding this issue is contained in Appendix 2. Table 1 summarizes the emission units that will be installed, modified or potentially affected by the project. The preliminary site arrangement is shown in Figure 2 and flow diagrams showing the proposed AQCS for EUSGUs 5 and 6, EUSGU 7, and EUSGUs 8 and 9 are shown in Figures 3a, 3b, 4, and 5, respectively.


There will be no new emergency generator(s), fire pump engine(s), or cooling tower(s) related to this project. Also, none of the existing emergency equipment will be affected by the project. 2.2.1 BOOSTED OVER FIRE AIR AND LOW NOX BURNERS FOR NOX CONTROL (EUSGUS

5 THROUGH 9) Individually boosted over fire air systems will be added to each EUSGU for NOX control. The boosted over fire air systems will inject higher pressure air streams into the boiler furnace section of each EUSGU to create additional turbulent mixing. The systems are anticipated to include the following equipment: ● Boosted Over Fire Air fan (all 5 boilers) ● Over Fire Air ports (approximately 24 ports per boiler anticipated), and modulating dampers with

actuators (all 5 boilers) ● New Low NOX burners (EUSGUs 5 and 6) 2.2.2 SDA SYSTEMS FOR SO2 AND ACID GAS CONTROL (EUSGUS 5, 6, AND 7) SDA systems work on the principle of injecting hydrated reagent (lime) slurry into the exhaust gas stream from an EUSGU. The hydrated reagent reacts with the SO2 and HAP acid gases mandated for control under the EGU MATS Rule, including hydrogen chloride [HCl] and hydrogen fluoride [HF]). The resulting particulate matter (PM) is then captured in the downstream PM control systems. SDA systems will be added to each of EUSGUs 5, 6, and 7 for SO2 and acid gas control. The general arrangement of the equipment associated with the SDAs will include absorber vessels (one per EUSGU) with atomizers; instrumentation, control devices and hopper accessories; inlet and outlet stub of ductwork; and inlet control dampers to the individual ducts to the atomizers. 2.2.3 DSI SYSTEMS FOR SO2 AND ACID GAS CONTROL (EUSGUS 8 AND 9)

DSI systems work on the principle of injecting a dry reagent directly into the exhaust gas stream from an EUSGU. The dry reagent reacts with the acid gases (e.g., SO2, HCl and HF) to neutralize them. The resulting PM is then captured in the downstream PM control systems. DSI systems will be installed on EUSGUs 8 and 9 for SO2 and acid gas control. The sorbent will be injected as far upstream in the ductwork as practical but downstream of the electrostatic precipitators (ESPs) to allow for maximum residence time for the absorption reaction to take place. The major components of the dry sorbent injection system are:


● Sorbent truck unloading station with blower, piping, air cooler, dehumidifier, motor control center, and instrumentation

● Sorbent storage silo (7-day storage anticipated) ● Sorbent milling system.

2.2.4 PAC FOR MERCURY CONTROL (EUSGUS 5 THROUGH 9)

PIPP currently utilizes PAC injection for control of Hg on EUSGUs 7, 8, and 9. Boilers 5 and 6 do not currently have a PAC injection system. In the revised configuration the existing PAC system will be used for EUSGUs 8 and 9 only, while a new and functionally equivalent PAC system will be added for EUSGUs 5, 6, and 7 to reduce Hg emissions and ensure compliance with the EGU MATS Rule. The new PAC system for EUSGUs 5, 6, and 7 will include the following components: ● PAC truck unloading station with blower, piping, air cooler, dehumidifier, and instrumentation ● PAC storage silo ● PAC metering and transport equipment 2.2.5 FABRIC FILTERS (EUSGUS 5 THROUGH 9) The project will utilize existing fabric filters for PM removal following the new SDAs and DSI. To allow for adequate fabric filter capacity and assure compliance with the EGU MATS Rule PM requirements as a surrogate for non-volatile HAP metals, the existing fabric filters will be reconfigured and the fabric filters and booster fans currently associated with retired EUSGUs 1 through 4 will be reused for EUSGUs 5 and 6. EUSGU 7 will utilize the EUSGUs 5 and 6 current fabric filters and EUSGUs 8 and 9 will continue use of the former EUSGUs 7 through 9 fabric filter. Air-to-cloth ratios are sufficient in this arrangement such that no internal fabric filter modifications are required. 2.2.6 BALANCE OF NEW PLANT EQUIPMENT ASSOCIATED WITH THE PROPOSED

MODIFICATION Lime Slurry Preparation and Feed System

Lime will be forwarded to each of the SDAs via a common lime storage, preparation, and forwarding system. This system includes: ● One pebble lime storage silo with vibrating outlet hopper and truck fill pipe ● One silo vent filter unit ● 2 x 100% rotary lime feeders


● 2 x 100% lime slaking units ● One lime slurry feed tank ● 2 x 100% lime slurry feed loop pumps ● One dilution water tank ● 2 x 100% dilution water loop pumps ● Slurry loop and dilution water piping and valves Pebble lime will be delivered via truck and pneumatically conveyed to a silo which has a bin vent filter. From the silo, the pebble lime is slaked into a lime slurry from which there should not be any fugitive emissions. Ash Collection System

The existing ash stream from the ESPs will be unaffected by these proposed additional emission control systems. On EUSGUs 5, 6, and 7, the removal of the injected lime reagent, as well as the addition of PAC, will result in an increased loading of PM on the fabric filters. The incorporation of DSI on EUSGUs 8 and 9, as well as the higher resulting PAC rates, will increase the PM loading rate on the former EUSGUs 7 through 9 fabric filter despite serving two boilers rather than three. The existing hopper storage areas for each of the fabric filters are sufficient for the increased PM loadings. This additional PM loading to these existing collection systems is not expected to increase the PM/PM10/PM2.5 emission rates from these systems. Increased PM loading only serves to increase the required filter cleaning cycles. The EUSGUs 5 and 6 fabric filters’ PM will be routed to the former EUSGUs 1 through 4 fabric filter ash collection system. The former EUSGUs 7 through 9 fabric filter’s ash removal system is not designed for the increased loading resulting from DSI and the associated PAC increase. A new stand-alone or supplementary ash system will be installed for PM removal from the EUSGU 8 and 9 fabric filter. The new EUSGUs 8 and 9 ash removal system is expected to have a conveying capacity of at least two times the planned production rate. The total removal rate from the EUSGUs 8 and 9 fabric filter in the new arrangement is estimated at 5,500 pounds per hour (lb/hr). The new system shall have a capacity of nominally 6 tons per hour (tph). While the existing ash storage silo capacity is considered sufficient, new exhausters and piping will be installed.


3.0 REGULATORY REVIEW 3.1 MICHIGAN REGULATIONS The following rules are potentially applicable for the project and are typical for boiler projects of this magnitude, including ancillary equipment. 3.1.1 AIR POLLUTION CONTROL RULE 201 – PERMIT TO INSTALL REQUIREMENTS Any process or process equipment installed after August 15, 1967, which may emit an air contaminant requires a Permit to Install prior to installation, construction, reconstruction, relocation, alteration, or modification unless specifically exempt. Due to physical changes necessary to accommodate the boosted over fire air systems for each EUSGU, Low NOX burners for EUSGUs 5 and 6, and the proposed installation of the additional downstream control (PAC, SDA and DSI systems), the proposed AQCS project requires a Permit to Install. 3.1.2 AIR POLLUTION CONTROL RULES 224 TO 230 – T-BACT REQUIREMENT FOR NEW

AND MODIFIED SOURCES OF AIR TOXICS AND HEALTH-BASED SCREENING LEVEL REQUIREMENT FOR NEW OR MODIFIED SOURCES OF AIR TOXICS

Michigan Department of Environmental Quality (MDEQ) Rules 224 to 230, effective November 10, 1998, apply with limited exceptions to any proposed, new, or modified process or process equipment for which an application for a Permit to Install is required and which emits a toxic air contaminant (TAC). A TAC is defined in Michigan rules as:

. . . any air contaminant for which there is no National Ambient Air Quality Standard (NAAQS) and which is or may become harmful to public health or the environment when present in the outdoor atmosphere in sufficient quantities and duration.

Rules 224 and 225 require emissions of TACs not exceed the following: ● Rule 224 – The maximum allowable emission rate that results from the application of the best

available control technology for toxics (T-BACT). ● Rule 225 – The maximum allowable emission rate that results in a predicted maximum ambient

impact above the Initial Threshold Screening Level (ITSL), the Initial Risk Screening Level (IRSL), or both.


3.1.2.1 AIR POLLUTION CONTROL RULE 224 – T-BACT REQUIREMENT FOR NEW AND MODIFIED SOURCE OF AIR TOXICS; EXEMPTIONS

The project is being undertaken in part for assuring future compliance with the EGU MATS Rule, 40 CFR 63 Subpart UUUUU. The EGU MATS Rule is the outgrowth of statutorily mandated studies and USEPA findings under §112(n) of the Clean Air Act. The preambles to the proposed rule, 77 FR 24976 (May 3, 2011), and final rule, 77 FR 9304 (Feb. 16, 2012), contain extended explanations by the USEPA related to the development of the EGU MATS Rule. In these discussions, USEPA explained that HAP (many of which are TACs) emissions from coal-fired units of the type which the project is intended to control can be placed into five groups: mercury, non-volatile metals, acid gases, non-dioxin/furan organics, dioxin/furan organics. The USEPA goes on to explain and justify emission limitations for PM, Hg and HCl as representing technically feasible and achievable levels of control (directly or as surrogates) for mercury, non-volatile metals, and acid gases. For both groups of organics, the USEPA recognized that “good combustion practice” operates to minimize these emissions and is the only practical technology available. As discussed in Section 5.0, “good combustion practice” is being proposed as BACT for CO, with an associated emission limitation. Accordingly, We Energies contends that the project’s AQCS, intended to satisfy the EGU MATs Rule’s emission limitations and the project’s “good combustion practice” BACT, satisfies any T-BACT applicable requirement under Rule 224. 3.1.2.2 AIR POLLUTION CONTROL RULE 225 – PREDICTED MAXIMUM IMPACTS OF TACS MDEQ Rule 225 requires that the predicted maximum ambient impact from emission of TACs from new and modified sources not exceed health-based screening levels. The screening level for a TAC is the maximum allowable concentration in the ambient air, averaged over a specified period of time. The concentration of a pollutant is predicted using an air dispersion modeling computer program. Compliance with applicable ITSLs and IRSLs is presented in Section 6. 3.1.3 AIR POLLUTION CONTROL RULE 301 – STANDARDS FOR DENSITY OF EMISSIONS Rule 301 establishes limitations for the density of particulate emissions. The proposed project is not expected to have any effect on the ability to continue to comply with the visible emissions limitations of Rule 301. Rule 301 limits visible emissions as follows: ● A 6-minute average of 20% opacity, except for one 6-minute average per hour of not more than

27% opacity. ● A limit specified by an applicable federal New Source Performance Standards (NSPS). ● A limit specified as a condition of a Permit to Install or Permit to Operate.


We Energies will continue to comply with the opacity limitations specified in Rule 301 by continued use of the state-of-the-art PM emissions control technology currently in use at this facility. 3.1.4 AIR POLLUTION CONTROL RULE 331 – EMISSION OF PARTICULATE MATTER Rule 331 (Table 31 A.1) stipulates that pulverized coal-fired boilers meet a PM emission limit contained in Figure 31 of the rule. The proposed project is not expected to have any effect on the ability of We Energies to comply with Rule 331. Currently, the EUSGUs are subject to a PM emission limit of 0.030 pound per million British thermal units (lb/MMBtu) heat input established under a 2007 Consent Decree, to which the State of Michigan is a party, and which has been incorporated into the Draft ROP found in Appendix 1. The limit is well below that required by Rule 331. We Energies will continue to comply with the PM limitations specified in Rule 331 due to the continued use of state-of-the-art PM emissions control technology. 3.1.5 AIR POLLUTION CONTROL RULE 401 – EMISSION OF SULFUR DIOXIDE FROM

POWER PLANTS Rule 401, Table 41 restricts the maximum sulfur in coal that may be burned in a boiler, which is 1.0% by weight. We Energies currently uses and will continue to use coal fuels that comply with this requirement. 3.1.6 AIR POLLUTION CONTROL RULE 801 – EMISSION OF OXIDES OF NITROGEN FROM

NON-SIP CALL SOURCES PIPP is currently subject to the requirements contained in Rule 801. The addition of NOX AQCS will help assure continued compliance with the Rule 801 requirements. 3.1.7 AIR POLLUTION CONTROL RULE 901 – NUISANCE ODORS AND DUST Rule 901 prohibits the emissions of air contaminants in quantities that cause either: ● Injurious effects to human health or safety, animal life, plant life of significant economic value, or

property. ● Unreasonable interference with the comfortable enjoyment of life and property. We Energies relies on its existing management systems and practices to comply with Rule 901. After the installation of the AQCS, We Energies will continue to rely on its existing management systems and practices to comply with this regulation.


Rule 901 is incorporated as a general condition in all Permits to Install and as this application otherwise demonstrates the AQCS project will assure compliance with the rule and the general condition. 3.1.8 MERCURY EMISSION LIMITATIONS

The Part 15 rules regulate mercury emissions from EGUs that utilize coal-based fuels serving a generator with a nameplate capacity of more than 25 MW. The use of PAC injection in all EUSGUs will assure compliance with the requirements of the Part 15 rules. 3.1.9 MICHIGAN’S PART 18 RULES – PSD PIPP is located in an area considered to be in attainment for all NAAQS criteria pollutants. PIPP is considered to be an existing major source as defined in the PSD rules.1

The proposed changes to the AQCS at PIPP will be a major modification for CO, but not for any other regulated NSR pollutants. The MDEQ implements the PSD program through its Part 18 Regulations, which implements federal PSD permitting requirements under the Michigan state implementation plan (SIP).

The provisions of the Part 18 Rules require that new major stationary sources and major modifications be carefully reviewed prior to construction to ensure compliance with the NAAQS, the applicable PSD increment concentrations, the requirement to apply BACT, solicit public comments prior to approval of the PTI, and other provisions. This application demonstrates that the project is not a major modification for the regulated NSR pollutants PM, PM10, PM2.5, SO2, NOX, VOC, sulfuric acid (H2SO4), lead metal (Pb), and HF because the emissions of each of these pollutants will not increase by the pollutant-specific PSD “significant” thresholds using a past actual to projected actual emission analysis. Additionally, the project is not a major modification for greenhouse gases (GHGs) because the project will result in an increase of GHGs of less than 75,000 tpy of CO2e.Therefore, GHGs in the context of the project are not subject to regulation.2

See Section 4.3 regarding the past actual to projected actual emission analysis for these pollutants.

CO is the only regulated NSR pollutant that will be subject to the PSD requirements as contained in Part 18. 3.2 FEDERAL REGULATIONS On March 25, 2010, the USEPA published a direct final approval to convert a conditional approval of the Michigan PSD SIP to full approval under Section 110 of the CAA. Thereby, references to PSD in this 1 Per 40 CFR 52.21(b)(2)(i) and MDEQ Rule 1801 (aa). 2 Michigan interprets its Part 18 Rules consistent with 40 CFR 52.21(b)(49).


application refer to Air Pollution Control Rules Part 18 – Prevention of Significant Deterioration of Air Quality. 3.2.1 NAAQS – ATTAINMENT STATUS CONSIDERATIONS PIPP is located in Marquette County, which is currently in compliance or unclassified for all NAAQS (SO2, NO2, CO, PM10, PM2.5, ozone, and lead). While the USEPA has yet to develop a rule or clear guidance for implementation of the 1-hour SO2 NAAQS standard of 75 ppb, it is anticipated that the State of Michigan will have to develop information through additional monitoring or modeling of sources for the purpose of determining whether the air shed in Marquette County can be demonstrated to be in attainment with the 1-hour standard and imposing emission limitations in a SIP to assure the achievement and maintenance of the 1-hour standard. The proposed AQCS project and its ability to control SO2 emissions will assure the ability of PIPP to comply with SIP requirements for the 1-hour SO2 NAAQS standard. 3.2.2 40 CFR 60 SUBPARTS D, Da – NSPS The NSPS typically require that new, reconstructed, or modified emission sources comply with emission limits found in the applicable standard(s). A source is subject if it is new, reconstructed, or modified3

after the date specified in an applicable NSPS, unless otherwise specified in an NSPS subpart.

40 CFR 60, Subpart D applies to EUSGUs that have a capacity equal to or greater than 250 million British thermal units per hour (MMBtu/hr) heat input, and contains emission-based performance standards for PM, SO2 and NOX. EUSGUs 7, 8 and 9 are subject to this NSPS and EUSGUs 5 and 6 are not because they were installed prior to the effective date of the NSPS Subpart D. This NSPS applies to EUSGUs that commence construction on or after August 17, 1971. 40 CFR 60, Subpart Da applies to EUSGUs similar as Subpart D, except that Subpart Da applies to units that commence construction, reconstruction or modification on or after September 18, 1978. Since PIPP EUSGUs 5, 6, 7, 8 and 9 each commenced construction prior to September 18, 1978, and have not been reconstructed or modified, Subpart Da has not applied. However, since PIPP will be making physical changes to each EUSGU as needed to incorporate a boosted over fire air system, Subsections 3.2.2.1 and 3.2.2.2 address “modification” and “reconstruction” to determine whether the EUSGUs would be subject to requirements in NSPS Subpart Da.

3 As defined in 40 CFR 60.2 and 40 CFR 60.14.


3.2.2.1 NSPS MODIFICATION ANALYSIS In general, a modification (see 40 CFR 60.14) is deemed to occur if there is a physical change to an existing facility which results in an increase in the emission rate to the atmosphere of any pollutant to which an applicable NSPS standard applies. PIPP will be making physical changes to the EUSGUs to accommodate the new AQCSs. Therefore, the next step is to determine whether the physical changes will result in a potential short-term increase in emissions for any pollutant regulated under the applicable NSPS. NSPS Subpart Da regulates PM, NOX and SO2. The proposed project is for the specific purposes of pollution control and will result in decreases in emissions of SO2 and NOX. CO emissions are not regulated by this NSPS. The potential short-term emissions of PM will not increase as a result of this project. In addition, subparagraph 60.14(e)(5) states that the following change shall not be considered a modification pursuant to the NSPS:

“The addition or use of any system or device whose primary function is the reduction of air pollutants, except when an emission control system is removed or is replaced by a system which the Administrator determines to be less environmentally beneficial.”

As the proposed project is to install an AQCS which is designed to reduce air pollutants, it is not considered a modification under the NSPS regulations. 3.2.2.2 NSPS RECONSTRUCTION ANALYSIS An existing facility becomes an affected facility, irrespective of any change in emission rate, when reconstruction occurs. Reconstruction under the NSPS regulations is defined in 40 CFR 60.15(b) as:

(b). . . replacement of components of an existing facility to the extent that (1) The fixed capital cost of the new components exceeds 50 percent of the fixed capital cost that would be required to construct a comparable entirely new facility, and (2) It is technologically and economically feasible to meet the applicable standards set forth in this part.

The cost test will be addressed first. If the facility does not meet the cost test, the technological and economical feasibility will not be reviewed. The NSPS requirements indicate the fixed capital cost refers to purchasing the depreciable components of the project. It does not include the labor necessary to install the components.


To make an assessment of whether reconstruction has been triggered by the project, it is necessary to determine the costs of the proposed changes and compare those costs to the anticipated cost of constructing an entirely new comparable facility. Under NSPS Subpart Da, each boiler would be considered an “affected facility;” therefore, the costs need to be considered on a “per boiler” basis. Budgetary quotes were obtained for an entirely new boiler (for each of EUSGUs 5, 6, 7, 8, and 9). Costs were also obtained to complete the boosted over fire air system for each EUSGU and costs for installing new low NOX burners for EUSGUs 5 and 6. All cost estimates were provided by the Owner’s Engineering firm. Since the cost needs to be considered on a “per boiler” basis, the analysis is for each boiler individually. EUSGUS 5 AND 6 The fixed capital cost of the proposed boosted over fire air system for EUSGUs 5 and 6 is $1,981,500 and the cost for Low NOX burners is $1,175,000, for a total capital cost of $3,156,500 on a per EUSGU basis. The fixed capital cost of an entirely new comparable affected facility for each of EUSGUs 5 and 6 is $240,000,000.4

The cost for the proposed changes to an EUSGU is significantly less than 50% of the cost for an entirely new comparable EUSGU (50% of the $240,000,000 cost is $120,000,000). Based upon this data, the proposed over fire air and low NOX burner changes do not constitute a reconstruction under the NSPS requirements.

EUSGUS 7, 8, AND 9 The fixed capital cost of the proposed boosted over fire air system is $2,146,300 on a per EUSGU basis for each of EUSGUs 7, 8, and 9. The fixed capital cost of an entirely new comparable affected facility for each EUSGU is $240,000,000 on a per EUSGU basis for each of EUSGUs 7, 8, and 9. The cost for the proposed over fire air changes to an EUSGU is significantly less than 50% of the cost for an entirely new comparable EUSGU (i.e., 50% of the $240,000,000 cost is $120,000,000). Based upon this data, the proposed changes do not constitute a reconstruction under the NSPS requirements. 3.2.3 40 CFR 60 SUBPARTS OOO– NSPS 40 CFR 60, Subpart OOO applies to non-metallic mineral processing plants that include each crusher, grinding mill, screening operation, bucket elevator, belt conveyor, bagging operation, storage bin, enclosed truck, or railcar loading station. PIPP is proposing using three mills to grind or size reagent prior to storage and injection. These mills will be enclosed in a building and will comply with the visible

4 This value is based on a conservative estimate of $3,000 per kilowatt hour for installed capacity.


emission limit of seven percent opacity from the building openings and a particulate emission limit of 0.014 grains per dry standard cubic foot from the vents. 3.2.4 NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS (NESHAPS) 3.2.4.1 40 CFR 63 SUBPART UUUUU - NESHAP On February 16, 2012, the U.S. Environmental Protection Agency (USEPA) promulgated a NESHAP for Coal and Oil-Fired Electric Utility Steam Generating Units and Standards of Performance for Fossil-Fuel-Fired Electric Utility, Industrial-Commercial-Institutional, and Small Industrial-Commercial-Institutional Steam Generating Units. Both new and existing EUSGUs are subject to the federal requirements for hazardous air pollutants (HAPs) upon the effective date of the rule. PIPP is subject to the requirements contained in 40 CFR 63 Subpart UUUUU for existing non-low rank virgin coal units. 3.2.5 FEDERAL ACID RAIN PROGRAM 40 CFR PARTS 72 THROUGH 76 The modified EUSGUs will continue to be subject to the provisions of the Federal Acid Rain Program requirements as specified in 40 CFR Parts 72 through 78. These regulations require a facility to obtain a Federal Acid Rain permit, hold adequate SO2 allowances in the source allowance tracking system to account for the previous year’s emissions, comply with NOX limitations, and install and operate continuous emissions monitoring (CEM) systems for SO2, NOX, and opacity. The modified EUSGUs will continue to operate the existing dilution-extraction CEM systems currently installed in accordance with the applicable requirements of 40 CFR Part 75. Any CEMs that are relocated or installed new as part of this project will be certified (or recertified) in accordance with 40 CFR Part 75.20. PIPP does not anticipate a need for recertification of the existing CEMS that will not be moved or changed as part of this project. 3.2.6 FEDERAL CAIR The Clean Air Interstate Rule (CAIR) was finalized in 2005. In December 2008, CAIR was rejected by the D.C. Circuit Court of Appeals but remained in place temporarily until the USEPA issued a new rule addressing the transport of air pollution across state boundaries. The rule replacement known as the Cross-State Air Pollution Control Rule (CSAPR) was finalized in July 2011; however on August 21, 2012, the D.C. Circuit issued a ruling to vacate CSAPR and CAIR remains in place pending the promulgation of a replacement rule. The applicability of CAIR at PIPP will not change as a result of this project. PIPP will continue to comply with the applicable CAIR requirements.


4.0 EMISSION CHARACTERISTICS This section addresses the emissions associated with the project. The primary emission units associated with the project are EUSGUs 5 through 9. There will also be fugitive emissions associated with vehicle traffic for the proposed AQCS and PM, PM10 and PM2.5 emissions associated with the new material storage and handling equipment for alkaline reagent and PAC. In order to determine whether a “major modification” will occur under PSD, facilities are allowed to calculate annual emission increases resulting from a proposed project by quantifying the difference between the projected actual emissions after the proposed change and the baseline actual emissions. Facilities are able to exclude from the projected actual emissions that portion of the emissions that are unrelated to the project and that could have been accommodated by the facility during the baseline period. Pursuant to the December 2002 “NSR Reform” regulations, incorporated into R336.2801 et seq., this type of analysis is generally referred to as an “actual-to-projected-actual” applicability test. In the case of PIPP, both affected existing and new emission units are part of the proposed project. As a result, a “hybrid” test has been used which calculates the projected actual emissions from each existing emission unit and the potential to emit of the new emission units. 4.1 APPLICABILITY DETERMINATION FOR PSD PIPP is one of the 28 listed source categories in the definition of a “major stationary source” found in R 336.2801(cc) and, therefore, is a major stationary source if the potential to emit of any regulated NSR pollutant is greater than or equal to 100 tpy. The existing power plant has a potential to emit greater than 100 tpy of a regulated NSR pollutant; therefore, the source is considered to be an existing major stationary source. A major modification for each regulated NSR pollutant occurs at an existing major stationary source if there is a significant emissions increase and a significant net emissions increase for that regulated NSR pollutant. This portion of the application will demonstrate that there will not be a significant emissions increase for regulated NSR pollutants, with the exception of CO, consistent with the provisions in Michigan’s Part 18 PSD rules. An “actual to projected actual” analysis was used to demonstrate that emissions of PM, PM10, PM2.5, SO2, NOX, VOC, H2SO4, Pb, and HF due to the proposed modifications would not result in a significant emissions increase. Additionally, the “actual to projected actual” analysis showed that because the increase in GHG is less than 75,000 CO2e, GHG is not subject to review.


4.1.1 BASELINE ACTUAL EMISSIONS The baseline actual emissions have been determined from a five-year period preceding the anticipated date that the Permit to Install application would be submitted to the MDEQ. The definition of “baseline actual emissions” from Michigan’s Rule 1801 is:

(b) "Baseline actual emissions" means the rate of emissions, in tons per year, of a regulated new source review pollutant, as determined by the following: (i) For any existing electric utility steam generating unit, baseline actual emissions means the average rate, in tons per year, at which the unit actually emitted the pollutant during any consecutive 24-month period selected by the owner or operator within the 5-year period immediately preceding when the owner or operator begins actual construction of the project. The department shall allow the use of a different time period upon a determination that it is more representative of normal source operation. All of the following provisions apply: (A) The average rate shall include fugitive emissions to the extent quantifiable, and emissions associated with startups, shutdowns, and malfunctions. (B) The average rate shall be adjusted downward to exclude any noncompliant emissions that occurred while the source was operating above an emission limitation that was legally enforceable during the consecutive 24-month period. (C) For a regulated new source review pollutant, if a project involves multiple emissions units, then only 1 consecutive 24-month period shall be used to determine the baseline actual emissions for the emissions units being changed. A different consecutive 24-month period may be used for each regulated new source review pollutant. (D) The average rate shall not be based on any consecutive 24-month period for which there is inadequate information for determining annual emissions, in tons per year, and for adjusting this amount if required by paragraph (i)(B) of this subdivision.

For proper review of the application, and in order to assure completeness of the application, the baseline actual emissions must be determined and provided in the application materials. In order to provide an accurate and reasonable baseline actual emission rate for the project, it would be necessary to review the past actual emissions five years prior to the date that the air use permit application is submitted to the MDEQ for review. Capturing baseline actual emissions during the agency’s review process (MDEQ technical review period, public comment participation process, etc.) and subsequent time period leading to beginning actual construction would be difficult to include, since this review period could be a lengthy process and actual emissions have not yet been produced for this period between application submittal and permit issuance. The MDEQ allows the permit applicant for a proposed project to rely on a five-year period that ends at or immediately prior to the submittal of a permit application for the establishment of the baseline actual emissions, for the purposes of determining whether a proposed project would be subject to Michigan’s Part 18 requirements. Furthermore, the definition of baseline actual emissions includes allowing the use of a different time period upon a determination that this period is more representative of normal source operation. The proposed five-year time period captures the use of this provision in Rule 1801, because it can be


demonstrated that the longer time period is more representative of normal source operation and, in fact, a longer time period could be justified. The time period chosen is appropriate for determining baseline actual emissions and seeks MDEQ’s agreement with its choice of the five-year period for this determination. The past five years of operation of the existing EUSGUs 5 through 9 have been evaluated to determine the baseline actual emissions. Table 2 depicts the baseline actual emissions selected as representative for this project. The rules require that a continuous 24-month period be used to determine the baseline actual emissions from a facility (EUSGUs 5 through 9) for each pollutant as an average annual rate, in tons per year. A different 24-month period can be used for different pollutants when determining the proposed project emission increases under R 336.2801(ee). For instance, a 24-month period for establishing baseline actual emissions for NOX can be a different 24-month period for SO2. The baseline actual emissions and associated 24-month time periods are summarized in Table 2. The monthly actual emission data for the past five years of operation that were used to determine the baseline actual emissions for each regulated NSR pollutant are included in Appendix 3. The detailed discussion regarding the methodology used to calculate the baseline emissions from the ancillary equipment is provided in Section 4.2. A summary of the baseline emissions from the ancillary equipment is provided in Appendix 6. 4.1.2 PROJECTED ACTUAL EMISSIONS For an affected existing emission unit, “projected actual emissions” are the maximum annual rate, in tpy, at which the emissions unit is projected to emit a pollutant in any 1 of the 5 years (12-month period) following the date the unit resumes regular operation after the project, or in any 1 of the 10 years following that date, if the project involves increasing the emissions unit's design capacity. Because the changes proposed for the PIPP are specifically related to the installation of AQCS and do not result in any increase in the design capacity of these emission units, We Energies believes that a 5-year projection is appropriate. For a new emission unit, “projected actual emissions” are its potential to emit that pollutant. The projected actual emissions have been determined by PIPP based on the projected utilization (based on power demand projections as reported to the Midwest Independent System Operator) for the five years following completion of the AQCS project and the emission rates expected after the modification. Documentation of the projected utilization is provided in Appendix 4. The projected actual emission calculations for the boilers are shown in Appendix 5.


The methodology used to calculate the projected actual emissions was the same as described for the baseline emission calculations; however, the equipment throughput and operating hours were adjusted to reflect the proposed boiler utilization rates. Projected actual emissions from the ancillary equipment are provided in Appendix 6. 4.1.3 EXCLUDED EMISSIONS When calculating the projected actual emissions after the project, an applicant may exclude that portion of a modified unit's emissions following the project that the existing unit could have accommodated during the consecutive 24-month period used to establish the baseline actual emissions and that are also unrelated to the particular project, including any emission increases resulting from increased utilization due to demand growth. For the purpose of determining what each EUSGU could have accommodated during the baseline period, the calendar month with the highest utilization during the baseline period has been identified. However, as previously stated the proposed project is for the specific purpose of installing and modifying the AQCS on each EUSGU and will not increase the gross generating capacity of each EUSGU (note that the net generating capacity of each EUSGU will be reduced as a result of the parasitic load from the new AQCS). Due to the economic recession during the 5 years preceding the commencement of the modification, each EUSGU is “capable of accommodating” greater utilization than was actually accommodated during that 5-year period. Excluded emissions have been determined for PM, PM10, PM2.5, SO2, NOX, VOC, H2SO4, Pb, HF and GHG in accordance with R 336.2801(ll)(ii)(C) and USEPA guidance. It is being conservatively assumed that the maximum monthly utilization actually achieved by each EUSGU during the baseline period is representative of the maximum utilization that could have been accommodated during that same period. Each EUSGU’s monthly maximum utilization was annualized and multiplied by the emission rates (lb/MMBtu) expected after the modification to determine the amount of emissions which could be excluded from the Projected Actual emissions. Selection of the maximum monthly utilization for each EUSGU is provided in the Past Heat Input Summary in Appendix 3a. The calculations of excluded emissions for each regulated NSR pollutant are shown in Table 3. The methodology used to calculate the capable of accommodating emissions was the same as described for the baseline emission calculations; however, the equipment throughput or operating hours were adjusted to reflect the utilization rates that the boilers were capable of accommodating during the baseline period. Excluded emissions from the ancillary equipment are provided in Appendix 6. The throughputs and hours of operation were scaled up based on a ratio of the rates that the boilers were capable of accommodating during the baseline period to the rates that actually occurred during the baseline period (2008 was used).


4.1.4 PROJECTED EMISSIONS INCREASE Table 3 provides an analysis for PM, PM10, PM2.5, SO2, NOX, VOC, H2SO4, Pb, and HF that includes the projected actual emissions, excluded emissions, baseline actual emissions, and resulting emission increase for each pollutant. The emissions increases associated with the project for each of these pollutants are not significant. Additionally, because the increase in GHG is less than 75,000 CO2e, GHG is not subject to review under NSR. 4.2 ANCILLARY PARTICULATE SOURCE EMISSIONS The potential for emissions of particulate matter exists from several ancillary sources at the PIPP including material receiving, handling, storage, and haul truck traffic. To the extent practical, PM emissions will be controlled by physical enclosures, fabric filter collectors, the use of dust suppression agents, or other readily available emission control techniques. The following sections detail the emission calculation methodology utilized for the ancillary sources at the PIPP. Table 3 provides an analysis for the projected actual emissions, excluded emissions, baseline actual emissions, and resulting emission increase for each pollutant. The detailed emissions summary for ancillary equipment is included in Appendix 6. 4.2.1 PAVED ROAD EMISSIONS Fugitive particulate emissions are generated when trucks drive over paved road surfaces, causing dust on the road source to become airborne. The particulate emissions from paved roads were calculated using USEPA AP-42 Section 13.2.1, Paved Roads (January 2011). This project will increase the delivery of PAC to existing sources utilizing it and will add deliveries of PAC, lime, and DSI. It is important to note that the increase in the delivery of PAC to existing sources will only be an increase on an annual basis, the maximum daily number of trucks will not be increasing as a result of the project. The emissions increase associated with the project for the paved roads was determined using the following methodology. Equation 2 in Section 13.2.1.3 was used to determine the particulate matter emission factor in units of pounds per vehicle mile traveled (lb/VMT). Equation 2 is outlined below.

𝐸𝐸 = [𝑘𝑘(𝑠𝑠𝑠𝑠0.91) × (𝑊𝑊1.02) ] �1 −𝑃𝑃

4𝑁𝑁�


Where:

E = particulate emission factor (lb/VMT) k = particle size multiplier (lb/VMT) sL = road surface silt loading (g/m²) W = average weight (tons) of the vehicles traveling the road P = number of wet days with at least 0.254 mm (0.01 in) of

precipitation during the averaging period N = Number of hours in the averaging period (e.g., 8760 for annual,

720 for monthly, etc.) The particle size multipliers (k) for PM, PM10 and PM2.5 were obtained from AP-42 Table 13.2.1-1. The number of wet days (P) was determined from AP-42 Figure 13.2.1-2, which is a map of the United States showing the mean number of days with 0.01 inches or more of precipitation. For Marquette Michigan, a P value of 150 days was used in the calculation. Table 13.2.1-2 was used to determine the road surface silt loading (sL). For the summer months (Mar-Nov), the default silt loading value of 0.6 g/m2 for normal roads with less than 500 vehicles per day was used and for winter months (Dec-Feb) the value of 2.4 g/m2, which assumes a multiplier of 4 times the default summer silt load, per Table 13.2.1-2 was used. To determine the emissions associated with the project from the haul roads, the VMT for each type of material delivered was determined and multiplied by the calculated emission factor. The VMT was determined based on the frequency of the truck delivery for each material and the calculated mileage for the associated truck route. 4.2.2 MATERIAL HANDLING EMISSIONS Fugitive particulate emissions are generated during the transfer of material (e.g., fly ash, PAC, DSI, etc.) throughout the process. The only material handling operations potentially affected by the project are fly ash handling and storage operations for the fly ash collected by the fabric filters and the new DSI silo. Particulate emissions from ash handling material transfers were calculated using USEPA AP-42 Section 13.2.4, Aggregate Handling and Storage Piles (November 2006). Equation 1 in Section 13.2.4.3 was used to determine the emission factor in pounds per ton (lb/ton) of material transferred. Equation 1 is outlined below:

𝐸𝐸 = 𝑘𝑘(0.0032) ��𝑈𝑈5�

1.3

÷ �𝑀𝑀2�

1.4

� Where:

E = particulate emission factor (lb/ton) k = particle size multiplier U = mean wind speed (miles per hour [mph]) M = material moisture content (%)


The aerodynamic particle size multipliers provided in Section 13.2.4.3 for Equation 1 were used in the calculations along with site specific moisture content for the coal and ash. The wind speed data for any open or partially enclosed sources was obtained from average meteorological data (2005-2009) from Sawyer International Airport in Gwinn, Michigan. The wind speed for enclosed transfers was assumed to be 1 mph. The emissions from the material transfers were then determined based on the material throughput and the calculated emission factor. A control efficiency of 75% was assumed for any transfer with a telescopic chute.5

Emissions from material handling operations, such as the new DSI, PAC, and Pebble Lime storage silos, which are controlled by add-on devices (e.g., fabric filters, bin vents) were calculated based on the exhaust flow rate (dscfm) and the outlet grain loading rate (gr/dscf). The outlet grain loading rates were based on manufacturer information, when available, and USEPA documentation of typical grain loading rates. 4.3 TAC AND HAP EMISSIONS Most TAC emissions are estimated based on emission factors provided in the USEPA’s Web FIRE database. The Hg and HCl emission estimates are based on 40 CFR 63 Subpart UUUUU for existing coal-fired electric utility steam generating units. Tables 4, 5, and 6 provide the short-term TAC pollutant emission rates for EUSGUs 5 and 6, EUSGU 7, and EUSGUs 8 and 9, respectively. A summary of the HAP emissions for each EUSGU and all EUSGUs combined is provided in Table 7.

5 A control efficiency of 75% is assumed per Section 6.2 of "Fugitive Emissions from Integrated Iron and Steel Plants" (EPA-600/2-78-050).


5.0 CARBON MONOXIDE PSD BACT ANALYSIS 5.1 GENERAL TOP-DOWN PSD BACT PROCESS PIPP is an existing pulverized coal-fired baseload electrical generating plant. Since the project does not include new boilers, this PSD BACT analysis for CO emissions is targeted at evaluating the potential control alternatives for the existing boilers. BACT requirements are intended to ensure that the emissions from each new and modified emission unit associated with a major source project will reflect the use of the latest best available air pollution control technologies. BACT evaluations require the documentation of performance levels achievable for a given control technology on a pollutant-by-pollutant basis. BACT is defined in the MDEQ-AQD Part 18 Rules as:

. . . an emissions limitation, including a visible emissions standard, based on the maximum degree of reduction for each regulated new source review pollutant, which would be emitted from any proposed major stationary source or major modification which the department – on a case-by-case basis, taking into account energy, environmental, and economic impacts and other costs – determines is achievable for such source or modification through application of production processes or available methods, systems, and techniques, including fuel cleaning or treatment or innovative fuel combination techniques for control of the pollutant. Application of best available control technology shall not result in emissions of any pollutant which would exceed the emissions allowed by any applicable standard under 40 CFR parts 60 and 61, adopted by reference in R 336.2801a. If the department determines that technological or economic limitations on the application of measurement methodology to a particular emissions unit would make the imposition of an emissions standard infeasible, then a design, equipment, work practice, operational standard or combination thereof, may be prescribed instead to satisfy the requirement for the application of best available control technology. The standard shall, to the degree possible, set forth the emissions reduction achievable by implementation of the design, equipment, work practice or operation, and shall provide for compliance by means which achieve equivalent results.

The USEPA draft guidance recommends a 5-step top-down approach be used when evaluating best available air pollution control technologies. This approach to the BACT process involves identifying all control alternatives with a practical potential for application to the emission unit under review. The control alternatives should include not only existing controls for the emission unit but also controls applied to similar emission units. Control technologies required as the Lowest Achievable Emission Rate (LAER) for an identical emission unit must also be included, typically as the most effective control alternative. If, on a case-by-case basis for the particular emission unit, an identified control alternative is not technically feasible, it can be eliminated from further review. The remaining control alternatives are ranked by control effectiveness. If it can be shown that the most effective control is impractical for energy, environmental, or economic reasons, it can be eliminated and the next most stringent level of control is similarly evaluated. The process continues until a control technology and associated emission level is determined which cannot be eliminated due to technical, energy, environmental, or economic reasons. The top-down BACT evaluation process is described in the draft document New Source Review Workshop


Manual (USEPA, 1990), and additional information can be found on the MDEQ website (http://www.deq.state.mi.us/aps/nsr_information.shtml). The five steps of a top-down BACT evaluation are: 1. Identify all available control options with practical potential for application to the specific emission unit

for the regulated pollutant under evaluation. 2. Eliminate technically infeasible or unavailable technology options. 3. Rank remaining control technologies by control effectiveness. 4. Evaluate the most effective controls and document the results; if the top option is not selected as

BACT, evaluate the next most effective control option. 5. Select BACT, which will be the most effective practical option not rejected based on energy,

environmental, and/or economic considerations. Step 1 of the process involves researching the control options available for a proposed emission unit. This is performed by reviewing: publically available documents; the USEPA RACT/BACT/LAER Clearinghouse (RBLC) database; recent permits issued by federal, state, and local agencies which may not be included in the RBLC database; and vendor information. The process can include evaluating less polluting processes, add-on control alternatives, fuel combustion equipment, and modifying the combustion method (i.e., using lower polluting processes or equipment). Step 2 involves eliminating those control technologies which are not technically feasible for the emission unit or which have not been demonstrated in practice for units similar to the proposed unit. Step 3 requires ranking the remaining feasible control technologies by control effectiveness. Step 4 evaluates the environmental, energy, and economic impacts of each control technology identified in Step 3. Step 5 - BACT is selected from the results of Steps 1 through 4. The top-down approach is used in this analysis to evaluate available control technologies for CO emissions from existing EUSGUs 5, 6, 7, 8, and 9, which are subject to PSD BACT for CO emissions.

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5.2 OTHER CONSIDERATIONS FOR DETERMINING BACT 5.2.1 DEMONSTRATED IN PRACTICE An emission limit proposed in a permit application does not automatically mean that that limit has been “achieved in practice” on a similar unit. Many PSD and LAER permits have been issued over the years for projects that were never constructed and, therefore, never operated. As a result, those emission limits have never been “achieved in practice.” There are also instances in which incorrect limits have been posted to the RBLC, or where the ultimate and final permit limits were subsequently modified prior to permit issuance. In some cases, an applicant may have proposed very stringent limits without a meaningful commercial guarantee, perhaps to avoid a more onerous requirement or an unacceptable air quality impact, and was then unable to continuously achieve the limits in practice. It is also very important

to note that an emission rate based on a BACT finding must be met continuously under all normal

operating conditions, not just at one optimal design point. Therefore, there must be a reasonable assurance that each BACT limit evaluated is truly “demonstrated in practice” on a similar unit, and can be continuously achieved under all expected operating conditions. 5.2.2 APPLICABLE NSPS AND NESHAPS By definition, BACT cannot be less stringent than any applicable NSPS under 40 CFR Part 60 or NESHAP under 40 CFR Part 61. There are currently no NSPS or NESHAP that could apply to Boilers 5 through 9 that include restrictions on CO emissions. 5.2.3 PREVIOUS BACT/LAER DETERMINATIONS The USEPA RBLC is a listing of RACT, BACT, and LAER determinations by governmental agencies for many types of air emission sources. PIPP consulted this database for other similar recently permitted sources as the first step in developing a list of the most recent BACT/LAER decisions for similar sources. The results of the RBLC search and information from more recent permits are summarized on a pollutant-specific/process-specific basis in the following sections to identify and rank alternative technologies and achievable levels of control. Recent RBLC search results for the various emission units undergoing BACT analysis are summarized in the tables in Appendix 7. The information from the RBLC was limited to the most recent five years of CO BACT determinations for similar processes and fuel types. We believe that these most recent BACT determinations provide a more accurate picture of currently available emission control technologies and targeted BACT emission limitations.


5.3 CARBON MONOXIDE TOP-DOWN BACT ANALYSIS CO is formed as a result of incomplete combustion of a fuel containing carbon. Formation of CO is controlled by providing adequate residence time, excess oxygen and adequate temperature in the combustion zone to ensure efficient combustion. In addition to the formation of CO, incomplete combustion also leads to increased emissions of PM, including unburned carbon, VOCs, and HAPs. Therefore, methods employed in order to reduce or control emissions of CO tend to reduce emissions of other pollutants as well, except for the potential increases in CO2 and NOX emissions. The procedure described above was used to determine the appropriate PSD BACT for CO emissions from each of the coal-fired boilers. All listings in the USEPA’s RBLC for coal-fired boilers similar to those at PIPP utilize combustion control techniques for CO. While gas-fired combustion turbines (CTs) and some gas-fired boilers have been equipped with oxidation catalyst control technology, this technology is not applicable to coal-fired boilers. In addition to oxidizing CO, an oxidation catalyst would oxidize SO2 to produce SO3, which results in the formation of sulfuric acid mist. The SO2 oxidation rate could be in the range of 5% or more resulting in very high sulfuric acid mist emissions. Finally, an oxidation catalyst would have to be located upstream of the particulate removal stage where flue gas temperatures are in the range of 800°F to 1,000°F, and would be exposed to the high solids loading of ash inherent to operation of a coal-fired boiler. In this environment, the oxidation catalyst would rapidly be eroded and fouled with solid particulate. Nonetheless, an oxidation catalyst system vendor was contacted to determine the technical feasibility of installing this system on a coal-fired boiler. Due to the high particulate loading of the flue gas, variable trace element concentration in the flue gas and the SO2 loading before air pollution control systems, the vendor stated that they could not provide a catalyst system for coal-fired applications. Consequently, oxidation catalyst systems are considered technically infeasible for application to the proposed modified boilers. An oxidation catalyst, therefore, does not represent a viable control alternative for any of the proposed boilers. There is also no history of “tail end” thermal or catalytic oxidizers being used to control CO emissions from utility scale coal-fired boilers. “Tail end” thermal oxidizers would require auxiliary fuel combustion to raise exhaust gases to a sufficient temperature for approximately 0.5 seconds to allow the oxidation reaction of CO to CO2 (a GHG). The combustion chamber must be designed to facilitate mixing of the large volume of exhaust gas and combustion air for an adequate residence time. Catalytic oxidizers employ catalyst beds to speed the conversion of CO to CO2 and allow the conversion to occur at lower temperatures as compared to other thermal oxidation controls. While the installation of a “tail end” oxidizer is theoretically possible, as with oxidation catalysts, this approach would require substantial


additional heat input from auxiliary fuel combustion. Despite these serious operational problems, catalytic oxidizers have been included in the individual BACT analyses below. 5.3.1 EUSGUS 5 AND 6 ANALYSIS Boilers 5 and 6 are identical boilers and are addressed together in this section since they both will be using a single PM control technology (ESPs followed by fabric filters). Therefore, they are addressed in this section since the BACT analysis would apply to both EUSGUs together. Step 1 – Identify CO Control Technologies The CO control technologies identified include: ● Catalytic oxidizer ● Thermal oxidizer ● Efficient combustion practices A catalytic oxidizer reduces the need for higher temperatures by the use of a catalyst. A catalyst consists of a substrate with a surface consisting of a precious metal such as platinum, palladium, or rhodium. These metals are effective in facilitating oxidation of CO to CO2 (a GHG), as well as organic compounds to water and CO2. An inlet temperature of 500°F to 650°F is necessary to achieve the oxidation reaction with the catalyst. Catalytic oxidizers are installed in the duct work venting the exhaust gases. A thermal oxidizer incorporates a higher temperature, usually a minimum of 1,400°F, to achieve oxidation of CO to CO2. A thermal oxidizer capable of handling the exhaust gas volume of EUSGUs 5 and 6 would require a large footprint to install due to the size of the unit, and this is a valid concern for this project, since the existing site is literally landlocked. Efficient combustion practices are incorporated into the design of the boiler furnace, where combustion occurs, that takes advantage of temperature, residence time, and turbulence for exposure to available oxygen, which maximizes oxidation of carbon to CO2. However, absolute, complete oxidation is not possible. Step 2 – Eliminating Control Technologies that are Not Considered Feasible

A catalytic oxidizer is technically not feasible if placed prior to a PM air pollution control device. The uncontrolled PM causes poisoning and fouling of the catalyst surface and then becomes ineffective. A


catalytic oxidizer would need to be installed after the PM control device for it to work effectively and prolong its useful life.

A thermal oxidizer cannot be installed in an existing boiler due to each existing boiler’s design for heat transfer. Therefore, a thermal oxidizer would need to be placed after the boiler. With the use of bagfilter control for PM emissions, the thermal oxidizer would need to be installed after the PM control device. Placing a thermal oxidizer prior to the bagfilter would jeopardize the integrity of the bagfilter material due to high inlet temperatures. The appropriate location for a thermal oxidizer would be after the add-on air pollution control equipment.

Nonetheless, both the catalytic oxidizer and thermal oxidizer are theoretically feasible and are carried forward for analysis.

Step 3 – Ranking the Remaining Control Technologies by Control Effectiveness The catalytic oxidizer is considered to be the highest ranked control since it would result in the least amount of CO mass emissions. Although the combustion of auxiliary fuel results in additional CO emissions, the additional CO emissions would be controlled by the catalyst. Furthermore, combusting auxiliary fuel for exhaust gas reheat will result in formation of collateral pollutants such as NOX and GHG. A thermal oxidizer would be the next most efficient; however, the CO generated from combustion of the reheat fuel would render the thermal oxidizer less efficient. Similar to the catalytic oxidizer, the combustion of auxiliary fuel will result in formation of collateral pollutants such as NOX and GHG. Efficient combustion would be the next ranked form of control and has proven to achieve very low CO emissions rates, as supported by the most recent RBLC determinations. Step 4 – Energy, Environmental, and Economic Impacts of Selected Controls The energy, environmental, and economic impacts are described below. Energy Impacts

Catalytic and thermal oxidizers involve the use of auxiliary fuel to reheat the boiler exhaust gas after passing through the fabric filter collector, which results in a significant energy impact. A catalytic oxidizer would result in approximately 186.5 MMBtu/hr of heat input to heat the exhaust gas for the proper inlet temperature to the catalyst. This heat input is considered to be a significant energy impact.


A thermal oxidizer uses much more fuel than a catalytic oxidizer due to the temperature necessary to carry out the oxidation reaction from CO to CO2. The heat input requirement for a thermal oxidizer is approximately 845 MMBtu/hr heat input to control CO. This heat input is considered to be a significant energy impact. Efficient combustion results in the potential for better extraction of heat since the exothermal reaction of converting CO to CO2 adds heat for the boiler. Therefore, efficient combustion would result in no negative energy impact. Environmental Impacts

No significant environmental impacts are expected as a result of using a catalytic oxidizer. The catalyst with precious metal as the active catalyst is sent for recovery since the value of the precious metal(s) warrants recovery. The resulting increase in CO2 emissions at 88% CO control would be 1,636 tpy from both EUSGUs. A “tail-end” thermal oxidizer would result in an additional 310 tpy of CO emissions and 432,649 tpy of CO2 due to using fuel to reheat the EUSGU’s exhaust gas. CO2 emissions would increase both from the combustion of fuel and oxidation of the exhaust gas CO to CO2. The additional CO2 emissions would be 1,487 tpy from the EUSGUs with 80% oxidation of the CO. The total CO2 emissions as a result of using a thermal oxidizer would be 434,285 tpy. Therefore, there are significant potential negative environmental impacts from the potential use of a thermal oxidizer. Efficient combustion would not result in any environmental impacts since there will be no solid or liquid waste generated.

Economic Impacts

The economic impact as a result of using a catalytic oxidizer for EUSGUs 5 and 6 is estimated to be $8,711 per ton of controlled CO. The economic impact of using a thermal oxidizer for each of Boilers 5 and 6 is estimated to be $30,924 per ton of controlled CO. Both of these costs are considered to be excessive for economic feasibility for CO PSD BACT. Refer to Appendix 8 for detailed analyses. Step 5 – Select BACT The most feasible method for controlling CO emissions from both EUSGUs 5 and 6 is efficient combustion, which is proposed to be an emission rate of 0.20 lb/MMBtu heat input, based on a 30 boiler operating day rolling average. This is less than the PSD BACT emission limit assigned to each of the


Platte Generating Station and Whelan Energy Station located in Nebraska of 0.50 lb/MMBtu, based on a 30 boiler operating day rolling average, which are comparable in size to EUSGUs 5 and 6. Both of these CO PSD BACT limits were established in August 2012, and represent the most current determinations for sources similar to the boilers installed at PIPP. The proposed BACT emission limit of 0.20 lb/MMBtu heat input, based on a 30 boiler operating day rolling average, includes startup/shutdown modes of operation. Work practices will be utilized during startup/shutdown events that include the boiler manufacturer’s recommended procedures. These work practices will serve to minimize CO emissions during a startup/shutdown event. Therefore, compliance with the proposed CO BACT emission limit with the proposed averaging time will be attained under all operating scenarios. 5.3.2 EUSGU 7 ANALYSIS EUSGU 7 is addressed separately in this section since it will not share a common PM control system with any other EUSGUs. Therefore, BACT technology can only be applied to this EUSGU as a separate unit. Step 1 – Identify CO Control Technologies The CO control technologies identified include: ● Catalytic oxidizer ● Thermal oxidizer ● Efficient combustion practices A catalytic oxidizer reduces the need for higher temperatures by the use of a catalyst. A catalyst consists of a substrate with a surface consisting of a precious metal such as platinum, palladium, or rhodium. These metals are effective in facilitating oxidation of CO to CO2 (a GHG), as well as organic compounds to water and CO2. An inlet temperature of 500°F to 650°F is necessary to achieve the oxidation reaction with the catalyst. Catalytic oxidizers are installed in the duct work venting the exhaust gases. A thermal oxidizer incorporates a higher temperature, usually a minimum of 1,400°F, to achieve oxidation of CO to CO2. A thermal oxidizer capable of handling the exhaust gas volume of EUSGU 7 would require a large footprint to install due to the size of the unit, and this is a valid concern for this project, since the existing site is literally landlocked. Efficient combustion practices are incorporated into the design of the boiler furnace, where combustion occurs, that takes advantage of temperature, residence time, and turbulence for exposure to available


oxygen, which maximizes oxidation of carbon to CO2. However, absolute, complete oxidation is not possible. Step 2 – Eliminating Control Technologies that are Not Considered Feasible

A catalytic oxidizer is technically not feasible if placed prior to a PM air pollution control device. The uncontrolled PM causes poisoning and fouling of the catalyst surface and then becomes ineffective. A catalytic oxidizer would need to be installed after the PM control device for it to work effectively and prolong its useful life.



Step 3 – Ranking the Remaining Control Technologies by Control Effectiveness The catalytic oxidizer is considered to be the highest ranked control since it would result in the least amount of CO mass emissions. Although the combustion of auxiliary fuel results in additional CO emissions, the additional CO emissions would be controlled by the catalyst. Furthermore, combusting auxiliary fuel for exhaust gas reheat will result in formation of collateral pollutants such as NOX and GHG. A thermal oxidizer would be the next most efficient; however, the CO generated from combustion of the reheat fuel would render the thermal oxidizer less efficient. Similar to the catalytic oxidizer, the combustion of auxiliary fuel will result in formation of collateral pollutants such as NOX and GHG. Efficient combustion would be the next ranked form of control and has proven to achieve very low CO emissions rates, as supported by the most recent RBLC determinations.


Step 4 – Energy, Environmental, and Economic Impacts of Selected Controls The energy, environmental, and economic impacts are described below. Energy Impacts

Catalytic and thermal oxidizers involve the use of auxiliary fuel to reheat the boiler exhaust gas after passing through the fabric filter collector, which results in a significant energy impact. A catalytic oxidizer would result in approximately 102.4 MMBtu/hr of heat input to heat the exhaust gas for the proper inlet temperature to the catalyst. This heat input is considered to be a significant energy impact. A thermal oxidizer uses much more fuel than a catalytic oxidizer due to the temperature necessary to carry out the oxidation reaction from CO to CO2. The heat input requirement for a thermal oxidizer is approximately 412.5 MMBtu/hr heat input to control CO. At 412.5 MMBtu/hr heat input, PIPP considers this to be a significant energy impact and should be ruled out due to energy impacts. Efficient combustion results in the potential for better extraction of heat since the exothermal reaction of converting CO to CO2 adds heat for the boiler. Therefore, efficient combustion would result in no negative energy impact. Environmental Impacts

No significant environmental impacts are expected as a result of using a catalytic oxidizer. The catalyst with precious metal as the active catalyst is sent for recovery since the value of the precious metal(s) warrants recovery. The resulting increase in CO2 emissions at 88% CO control would be 895 tpy from EUSGU 7. A “tail-end” thermal oxidizer would result in an additional 170 tpy of CO emissions and 236,933 tpy of CO2 due to using fuel to reheat the EUSGU’s exhaust gas. CO2 emissions would increase both from the combustion of fuel and oxidation of the exhaust gas CO to CO2. The additional CO2 emissions would be 895 tpy from the EUSGU with 80% oxidation of the CO. The total CO2 emissions as a result of using a thermal oxidizer would be 237,828 tpy. Therefore, there are significant potential negative environmental impacts from the potential use of a thermal oxidizer. Efficient combustion would not result in any environmental impacts since there will be no solid or liquid waste generated.


Economic Impacts

The economic impact as a result of using a catalytic oxidizer for EUSGU 7 is estimated to be $8,732 per ton of controlled CO. The economic impact of using a thermal oxidizer for EUSGU 7 is estimated to be $30,994 per ton of controlled CO. Both of these costs are considered to be excessive for economic feasibility for CO PSD BACT. Refer to Appendix 8 for detailed analyses. Step 5 – Select BACT The most feasible method for controlling CO emissions from EUSGU 7 is efficient combustion, which is proposed to be an emission rate of 0.20 lb/MMBtu heat input, based on a 30 boiler operating day rolling average. This is less than the PSD BACT emission limit assigned to each of the Platte Generating Station and Whelan Energy Station located in Nebraska of 0.50 lb/MMBtu, based on a 30 boiler operating day rolling average, which are comparable in size to EUSGU 7. Both of these CO PSD BACT limits were established in August 2012, and represent the most current determinations for sources similar to the boilers installed at PIPP. The proposed BACT emission limit of 0.20 lb/MMBtu heat input, based on a 30 boiler operating day rolling average, includes startup/shutdown modes of operation. Work practices will be utilized during startup/shutdown events that include the boiler manufacturer’s recommended procedures. These work practices will serve to minimize CO emissions during a startup/shutdown event. Therefore, compliance with the proposed CO BACT emission limit with the proposed averaging time will be attained under all operating scenarios. 5.3.3 EUSGUS 8 AND 9 ANALYSIS EUSGUs 8 and 9 are identical boilers and share a common PM control system (separate ESPs followed by a common fabric filter). Therefore, they are addressed in this section since the BACT analysis would apply to both EUSGUs together. Step 1 – Identify CO Control Technologies The CO control technologies identified include: ● Catalytic oxidizer ● Thermal oxidizer ● Efficient combustion practices


A catalytic oxidizer reduces the need for higher temperatures by the use of a catalyst. A catalyst consists of a substrate with a surface consisting of a precious metal such as platinum, palladium, or rhodium. These metals are effective in facilitating oxidation of CO to CO2, as well as organic compounds to water and CO2. An inlet temperature of 500°F to 650°F is necessary to achieve the oxidation reaction with the catalyst. Catalytic oxidizers are installed in the duct work venting the exhaust gases. A thermal oxidizer incorporates a higher temperature, usually a minimum of 1,400°F, to achieve oxidation of CO to CO2. A thermal oxidizer capable of handling the exhaust volume for EUSGUs 8 and 9 would require a large footprint to install due to the size of the unit, and this is a valid concern for this project, since the existing site is literally landlocked. Efficient combustion practices are incorporated into the design of the boiler furnace, where combustion occurs, that takes advantage of temperature, residence time and turbulence for exposure to available oxygen, which maximizes oxidation of carbon to CO2. However, absolute, complete oxidation is not possible. Step 2 – Eliminating Control Technologies that are Not Considered Feasible

A catalytic oxidizer is technically not feasible if placed prior to a PM air pollution control device. The uncontrolled PM causes poisoning and fouling of the catalyst surface and causes it to become ineffective. A catalytic oxidizer would need to be installed after the PM control device for it to work effectively and prolong its useful life.



Step 3 – Ranking the Remaining Control Technologies by Control Effectiveness The catalytic oxidizer is considered to be the highest ranked control since it would result in the least amount of CO mass emissions. Although the combustion of auxiliary fuel results in additional CO emissions, the additional CO emissions would be controlled by the catalyst. Furthermore, combusting auxiliary fuel for exhaust gas reheat will result in formation of collateral pollutants such as NOX and GHG.


A thermal oxidizer would be the next most efficient; however, the CO generated from combustion of the reheat fuel would render the thermal oxidizer less efficient. Similar to the catalytic oxidizer, the combustion of auxiliary fuel will result in formation of collateral pollutants such as NOX and GHG. Efficient combustion would be the next ranked form of control and has proven to achieve very low CO emissions rates, as supported by the most recent RBLC determinations. Step 4 – Energy, Environmental, and Economic Impacts of Selected Controls The energy, environmental, and economic impacts are described below. Energy Impacts

Catalytic and thermal oxidizers involve the use of auxiliary fuel to reheat the boiler exhaust gas after passing through the fabric filter collector, which results in a significant energy impact. A catalytic oxidizer would result in approximately 118 MMBtu/hr of heat input to heat the exhaust gas for the proper inlet temperature to the catalyst. This heat input is considered to be a significant energy impact and should be ruled out due to energy impacts. A thermal oxidizer uses much more fuel than a catalytic oxidizer due to the temperature necessary to carry out the oxidation reaction from CO to CO2. The heat input requirement for a thermal oxidizer is approximately 815 MMBtu/hr heat input to control CO. At 815 MMBtu/hr heat input, PIPP considers this to be a significant energy impact and should be ruled out due to energy impacts. Efficient combustion results in the potential for better extraction of heat since the exothermal reaction of converting CO to CO2 adds heat for the boiler. Therefore, efficient combustion would result in no negative energy impact. Environmental Impacts

No significant environmental impacts are expected as a result of using a catalytic oxidizer. The catalyst with precious metal as the active catalyst is sent for recovery since the value of the precious metals warrants recovery. The resulting increase in CO2 emissions at 88% CO control would be 1,791 tpy from each boiler. The catalytic oxidizer and efficient combustion would not result in any non-air quality environmental impacts since there will be no solid or liquid waste generated.


The thermal oxidizer would result in an additional 300 tpy of CO emissions and 417,326 tpy of CO2 due to using fuel to reheat the EUSGU’s exhaust gas. CO2 emissions would increase both from the combustion of fuel and oxidation of the EUSGU exhaust gas CO to CO2. The additional CO2 emissions would be 1,628 tpy from the EUSGUs with 80% oxidation of the CO. The total additional CO2 emissions as a result of using a thermal oxidizer would be 418,954 tpy. Therefore, there are significant potential negative environmental impacts from the potential use of thermal oxidation CO control technologies. Economic Impacts

The economic impact as a result of using a catalytic oxidizer for EUSGUs 8 and 9 is estimated to be $6,235 per ton of controlled CO. The economic impact of using a thermal oxidizer for EUSGUs 8 and 9 is estimated to be $27,308 per ton of controlled CO. Both of these costs are considered to be excessive for economic feasibility for CO PSD BACT. Refer to Appendix 8 for detailed analyses. Step 5 – Select BACT The most feasible method for controlling CO emissions from each of EUSGUs 8 and 9 is efficient combustion, which is proposed to be an emission rate of 0.20 lb/MMBtu heat input, based on a 30 boiler operating day rolling average. This is less than the PSD BACT emission limit assigned to each of the Platte Generating Station and Whelan Energy Station located in Nebraska of 0.50 lb/MMBtu, based on a 30 boiler operating day rolling average, which are comparable in size to EUSGUs 8 and 9. Both of these CO PSD BACT limits were established in August 2012. The proposed BACT emission limit of 0.20 lb/MMBtu heat input, based on a 30 boiler operating day rolling average, includes startup/shutdown modes of operation. Work practices will be utilized during startup/shutdown events that include the boiler manufacturer’s recommended procedures. These work practices will serve to minimize CO emissions during a startup/shutdown event. Therefore, compliance with the proposed CO BACT emission limit with the proposed averaging time will be attained under all operating scenarios.


6.0 AIR QUALITY MODELING AND AIR TOXIC EVALUATION As discussed in previous sections of this application, We Energies is proposing to install the AQCS to reduce potential NOX, SO2, and Hg emissions from existing EUSGUs 5, 6, 7, 8, and 9 at the PIPP. As described in Section 4.3.The emission increase of CO exceeds the significant emission thresholds established pursuant to Michigan Rule 1802 (R 336.1802). The emission increases for the remaining pollutants regulated under the PSD regulations (PM, PM10, PM2.5, SO2, NOX, VOC, H2SO4, Pb, and HF) are below the significant emission thresholds. Pollutants with emission increases less than significant emission thresholds are not required to undergo a modeling demonstration pursuant to federal guidelines. However at our December 14, 2012 meeting, the MDEQ requested an analysis to show that the emissions changes associated with the project do not cause a significant impact for short-term averaging times for PM10, PM2.5, SO2, and NOX. In order to demonstrate this, an air dispersion modeling analysis has been conducted. A description of the emission units included in this analysis is noted in Section 6.1.5. Consistent with Michigan regulations, a PSD modeling demonstration has been completed for CO. Further, as stated in Rule 225 (R 336.1225) of the Air Pollution Control Commission General Rules, the MDEQ requires that the ambient impact of the TACs released from a rule subject source be estimated and compared to established air quality standards. Model selection and input parameters, used for both criteria pollutant and TAC modeling analyses, are presented in Section 6.1. A modeling demonstration for short-term PM10, PM2.5, SO2 and NOX is provided in Section 6.2. PSD modeling for CO is presented in Section 6.3, and TAC modeling is presented in Section 6.4. Michigan’s PSD regulations also require, when applicable, that facilities within 100 kilometers (km) of a PSD Class I area perform a modeling evaluation of the ambient air quality in terms of Class I PSD Increments and Air Quality Related Values (AQRVs). In addition, large projects beyond 100 km (but less than 300 km) from the nearest Class I area may be requested to conduct an evaluation of air quality impacts by the Federal Land Managers. The nearest Class I area to the project is the Seney National Wildlife Refuge, which is located 96 km southeast of the project. The Forest County Potawatomi Class I area in Forest County, Wisconsin, is approximately 120 km southwest of the project. Isle Royale National Park is the next closest Class I area and is approximately 170 km northwest of the project. The Class I evaluation is further addressed in Section 6.3. As can be noted from Table 3, projected actual emissions from the project indicate a reduction in some of the pollutants associated with visibility impairment (SO2, NOX, HF, and H2SO4). PM2.5 will increase, but by


only 8.8 tpy, which is less than the PSD significance threshold of 10 tpy. CO, the only pollutant for which the project is major, does not contribute to visible emissions. It is anticipated that there will be a reduction in visibility impairing emissions based on actual emissions, primarily due to the large reductions in SO2 and NOX emissions. 6.1 MODEL INPUT PARAMETERS 6.1.1 MODEL SELECTION The model selected for the air dispersion analysis was AERMOD, Version 12345. This model was established as the USEPA-preferred air dispersion model effective December 9, 2005, for steady-state operations. AERMOD is a modeling system which incorporates air dispersion based on planetary boundary layer turbulence structure and scaling concepts, including treatment of both surface and elevated sources, and both simple and complex terrain. 6.1.2 GEP STACK HEIGHT ANALYSIS Prior to running the air dispersion model, the potential for building downwash to affect the plume must be evaluated. Building downwash represents the effect that nearby structures have on the air flow near the stack. If the stack is within the area of influence of the building, the swirls and eddies caused by obstruction of the air flow near buildings can affect the plume dispersion. The GEP analysis was performed using the USEPA BPIP-Prime code for calculating projected building widths. This analysis was run for all buildings illustrated in Figure 1. The highest calculated GEP stack height of any structure was 400 feet (121.9 meters). Following the project, the stack height for Boilers 5, 6, and 7 will be 400 feet, equivalent to GEP. The actual stack height for Boilers 8 and 9 is 410 feet, exceeding GEP. Therefore, the GEP stack height of 400 feet is being used for Boilers 8 and 9 in the modeling analysis. The stack heights are listed in Table 8. Although the boilers are at GEP, AERMOD calculates direction-specific building effects, which were entered into the dispersion model as described in the next section. A summary of the results of the GEP analysis is presented electronically in Appendix 9. The direction-specific building dimensions calculated during the GEP stack height analysis were input into the model.


6.1.3 TERRAIN DATA Figure 1 presents the site topography. Actual terrain data were used in the model. The terrain elevation for each receptor point was determined using U.S. Geological Survey (USGS) 1/3 arc-second National Elevation Dataset (NED) data. The data, obtained from the USGS, has terrain elevations at 10-meter intervals. The terrain height for each individual modeled receptor was determined by assigning the interpolated height from the digital terrain elevations surrounding each modeled receptor. In addition, the AERMOD terrain processor, AERMAP (version 11103), was used to compute the hill height scales for each receptor. AERMAP searches all NED points for the terrain height and location that have the greatest influence on each receptor to determine the hill height scale for that receptor. AERMOD then uses the hill height scale in order to select the correct critical dividing streamline and concentration algorithm for each receptor. 6.1.4 RECEPTOR GRIDS Boundary receptors were placed at 25-meter intervals around this property line. Dense grids of 25-meter intervals surround the property out to 500 meters and 50-meter intervals out to 1,000 meters. Grids of 100 meters and 250 meters cover the outlying areas out to 10,000 meters. 6.1.5 METEOROLOGICAL DATA The 1-minute meteorological data used in the model was from Munising, Michigan, 2007-2011 (Surface Station No. 54813), and Gaylord, Michigan, 2007-2011 (Upper Air Station No. 4837). The MDEQ recommended use of Munising data due to its proximity to the facility, the availability of 1-minute meteorological data, and its location on the lake being similar to PIPP. The meteorological data was provided by the MDEQ and was processed using AERMET, Version 12345. The model for NOX, SO2 and PM2.5 was run using a combined 5-year meteorological dataset to determine the maximum 5-year average impact at each receptor. 6.1.6 BUILDING PARAMETERS The building parameters were input in the model. Appendix 10 contains the building identification and description as well as the associated building parameters.


6.1.7 SOURCE PARAMETERS 6.1.7.1 POINT SOURCE PARAMETERS Sources that will have emissions exhausted from a stack were considered point sources in the model. Table 8 provides the source characteristics used in the model. The model was run for the emission rates for each pollutant from each stack, considering a combined impact from all sources, including point sources, and volume sources (described in Section 6.1.4.3). 6.1.7.2 VOLUME SOURCE PARAMETERS Pursuant to MDEQ guidance for modeling fugitive emission sources, a volume source was used to simulate emissions that initially disperse in three dimensions with no plume rise. Specifically, the guidance recommends using volume sources to simulate roadway emissions from vehicles, emissions from conveyor transfers, and emissions from truck loading activities. Model input parameters for the volume sources are provided in Table 9. Following is a discussion of the calculations used to determine the volume source parameters for each type of source. 6.1.7.2.1 Haul Truck Traffic Pursuant to the USEPA’s Haul Road Guidance presented at the 10th Modeling Conference by Randy Robinson, haul truck traffic was simulated as a volume source using the modeling input parameters derived as follows:

Side Length of Volume = Truck Width + 6 meters Height of Volume = Vehicle Height x 1.7 Release Height = Height of Volume / 2.0 Initial Vertical Dimension = Height of Volume / 2.15 Initial Horizontal Dimension = Center to Center Distance / 2.15

Table 9 provides the model input parameters derived from the above equations. Appendix 11 provides the specifications of the haul trucks. Because the User’s Guide for AERMOD does not provide guidance for all types of sources, Volume II of the User’s Guide for the Industrial Source Complex (ISC3) Dispersion Models was referenced for determining the center-to-center distance between the volume sources. This guidance recommends using a maximum spacing of 2 times the width of the volume source as the center-to-center distance when using a string of volume sources to represent a line source. Therefore, 2 times the width of the volume source was the dimension used as the spacing. The haul truck traffic associated with the new deliveries of DSI, PAC, and pebble lime will be the only truck traffic


changing as a result of the project on the short-term basis. Any existing truck traffic which will be affected by the project will not be affected on a short-term basis, only the annual utilization will be affected. 6.1.7.2.2 Truck Loading Emissions from loading trucks with fly ash were modeled as volume sources pursuant to the MDEQ guidance. Trucks usually drive under a bin or silo where material is dropped into the truck via an open chute (for wet material) or telescopic chute (for dry material). The dimensions of the volume sources were derived as follows:

Release Height = Midpoint of material drop distance (between chute opening and truck top) Initial Horizontal Dimension = Width of Bin or Silo / 4.3 Initial Vertical Dimension = Height of Bin or Silo / 2.15

Table 9 provides the model input parameters derived from the above equations. 6.1.8 SHORT-TERM EMISSION RATES The model includes existing sources which will see a change in stack location or exhaust parameters. As only the project emission increase must be included in the significant modeling, emission rates of these units were included by using the past actual emission rate entered as a negative value with the existing stack parameters and the future potential emission rate entered as a positive emission rate with the new stack parameters. The only existing emission points which will see a change in stack location or exhaust parameters are Boilers 5 through 9. All other existing affected emission units at the facility will see no changes in stack location or exhaust parameters. Additionally, while some emission units may see an increase in annual utilization, none will see an increase in the daily emission rate as a result of the project. Therefore, these existing affected emission units were not included in the short-term SIL modeling. All new emission points were included in the model, using the future potential emission rate. SIL modeling for the various pollutants is further addressed in Sections 6.2 and 6.3. 6.1.8.1 PAST ACTUAL SHORT-TERM EMISSION RATES The past actual emission rates used in the model for the boilers were determined based on actual emissions for the month as measured by CEMS for NOX and SO2, and actual operating hours for the month. The PM10 and PM2.5 emissions were calculated monthly based on monthly heat input as reported from the CEMS and using stack testing data for the filterable portion of the emissions and adding the


AP-42 condensable emissions. Short-term past actual emission rate calculations for the boilers are provided in Appendix 12. 6.1.8.2 FUTURE POTENTIAL SHORT-TERM EMISSION RATES CO emissions are based on the proposed PSD BACT limit of 0.20 lb/MMBtu heat input based on a 30 boiler operating day rolling average for each of EUSGUs 5 through 9. NOX and SO2 emissions are based on the targeted emission rates for each EUSGU using the boosted over fire air systems (and new Low NOX burners for EUSGUs 5 and 6) for NOX control, and reagent injection for SO2 control. NOX emissions are targeted to meet 0.25 lb/MMBtu heat input for each EUSGU. SO2 emissions for EUSGUs 5, 6, and 7 are targeted to be 0.08 lb/MMBtu heat input; and for EUSGUs 8 and 9, the SO2 emissions are targeted to be 0.45 lb/MMBtu heat input. PM10 and PM2.5, emission rates are based on control efficiencies from the existing electrostatic precipitators, fabric filters, and future acid gas control. In the case of calculating PM10 and PM2.5 condensable emission rates for the pre- and post-change scenarios, We Energies assumes that these two pollutants will be reduced once the additional SO2 and NOX emission controls are added to these EUSGUs. Based on all this information, We Energies is estimating a PM10 and PM2.5 emission rate of 0.024 lb/MMBtu heat input. Tables 4, 5, and 6 provide the regulated NSR pollutant emission rates for EUSGUs 5 and 6, EUSGU 7, and EUSGUs 8 and 9, respectively. Table 8 provides a summary of the daily average pound per hour emission rates used in the model for the ancillary equipment. 6.2 MODELING ANALYSIS FOR SHORT-TERM PM10, PM2.5, SO2, AND NOX As requested by the MDEQ, an analysis has been completed for the short-term averaging times for PM10, PM2.5, SO2 and NOX. Determination of the past actual short-term emission rates and the future potential short-term emission rates, as used in the SIL analysis, were previously described in Section 6.1.5. The impacts resulting from the increase in emissions are less than the applicable SILs, for all pollutants, excluding NOX; therefore, no additional modeling has been conducted for PM10, PM2.5, and SO2. SIL modeling is discussed in Section 6.2.1, with additional NOX modeling addressed in Section 6.2.2.


6.2.1 SIGNIFICANT IMPACT ANALYSIS AND RESULTS The first step in the modeling demonstration is to conduct a significant impact analysis. In this analysis, the emission changes are modeled to determine if the emission changes will exceed the SIL defined in 40 CFR 52.21. If the impact for a pollutant exceeds the SIL, further modeling may be requested by the MDEQ. (Because the emission changes for these four pollutants are below the significant emission thresholds, PSD modeling requirements do not apply.) The emission rates used in the SIL analysis are provided in Table 8. As presented in Table 10, predicted impacts are below applicable SILs for PM10, SO2 and below the PM2.5 SIL previously promulgated. Therefore, no further modeling has been conducted for these pollutants. For NOX, the predicted impact exceeds the 1-hour SIL. Therefore, NAAQS modeling for NOX is discussed in Section 6.2.4. A CD containing the electronic model input/output files is provided in Appendix 9. 6.2.2 NAAQS ANALYSIS - NOX Because the impact from the proposed project exceeded the 1-hour NOx SIL, a NAAQS analysis has been performed at the request of the MDEQ. While PSD regulations require that facilities perform an increment and NAAQS analysis for all pollutants for which the impact from the proposed project exceeds the SIL because the proposed project is not subject to PSD for NOX, the PSD increment analysis is not required. In addition, there is currently not a PSD increment for short-term NOX impacts. The first step in the analysis is to define the significant impact receptors for the project. These are the receptors from the SIL analysis where the impacts from the project were determined to exceed the SIL. The MDEQ was contacted to determine what additional sources should be considered in the requested NAAQS analysis. The additional source data provided by the MDEQ is presented in Appendix 13. The model input parameters, except for the UTM coordinates, for each source contained in the MDEQ information were entered into the model as obtained from the table provided. The UTM coordinates provided by the MDEQ appeared to be in a different coordinate system than was used in the SIL analysis. Therefore, the UTM coordinates for the additional sources were entered into the model in NAD83 coordinate system to match the model setup. NAD83 coordinates for the additional sources were obtained using the Terrain Navigator software and aerial photos. The model was run as described in Section 6.1; however, in addition to the proposed PIPP sources, the existing PIPP emission sources (see Appendix 14), and those sources provided by the MDEQ were entered into the model. For the existing PIPP sources, the annual average NOX emission rates were used as the model input emission rate, because the only additional PIPP sources are emergency equipment.


To calculate the annual average emission rate for the existing emergency equipment, 500 hr/yr of operation was used. The model was run for a combined impact from all sources that should be considered in the NAAQS analysis. The results of the NAAQS analysis, which demonstrate compliance with the NAAQS, are presented in Table 11. A CD containing the electronic model input/output files is provided in Appendix 9. 6.3 PSD MODELING ANALYSIS FOR CARBON MONOXIDE CO is the only pollutant subject to PSD for this AQCS project. A significant impact analysis will be performed as described in Section 6.3.1. If emissions result in impacts that exceed the SILs, a detailed dispersion modeling impact analysis for compliance with the NAAQS is required as a part of the application. (No PSD increments have been established for CO; therefore, no increment modeling is required.) 6.3.1 SIGNIFICANT IMPACT ANALYSIS AND RESULTS The significant impact analysis is the first step in the PSD modeling. Emissions for CO are modeled to determine if the emissions increases will exceed the SILs defined in 40 CFR 52.21. If the impact for a pollutant exceeds the SIL, NAAQS modeling must be performed for the facility. If the impact for a pollutant meets the SIL, NAAQS modeling is not required. The past actual and future potential emission rates used in the SIL analysis are described in Section 6.1.5 and are provided in Table 9. As presented in Table 10, predicted impacts are below the SILs. Therefore, no further modeling is required. As emissions of CO are subject to PSD requirements, CO emissions during startup/shutdown conditions have been evaluated through dispersion modeling to demonstrate compliance with the short-term NAAQS. Emission rates and exhaust flow parameters can fluctuate greatly under these conditions. The boilers at PIPP warm up during a cold start by burning 100% fuel oil. Once the boiler is warmed up, solid fuel can be added to the boiler. The current ROP limits these conditions as follows: Periods of startup shall not exceed two hours after any amount of coal is combusted. Periods of shutdown shall only commence when the unit ceases burning any amount of coal. Because the exhaust parameters fluctuate greatly during startup/shutdown, it is difficult to measure emissions during these conditions. On each of the EUSGUs, PIPP currently has CO CEMs which are not certified, but rather are used for informational purposes only. Therefore, no past actual emissions are available for startup/shutdown modeling of CO. The non-certified CO CEMs data was reviewed for past periods of startup/shutdown in order to determine a rough estimate of how startup/shutdown emissions might compare to emissions at baseload.


An emission rate of three times the potential emission rate at baseload operations at 100% capacity was used as a conservative estimate in the modeling analysis. This is representative of the worst-case 24-hour emission rate that is expected from the boilers. The model was run assuming all 5 boilers were operating simultaneously in this worst-case model. As presented in Table 11, predicted impacts under the worst case assumptions for the startup/shutdown are below the SILs. Therefore, no further modeling assessment is required. A CD containing the electronic model input/output files is provided in Appendix 9. 6.3.2 PSD CLASS I INCREMENTS CO is the only pollutant subject to PSD review and therefore a Class I impact assessment would technically be required. However, no PSD Class I increments have been established for CO; therefore, no Class I modeling has been conducted. 6.4 TAC MODELING In Rule 225 (R 336.1225) of the Air Pollution Control Commission General Rules, the MDEQ requires that the ambient impact of the TACs released from a rule-subject source be estimated and compared to established air quality standards. Although mentioned previously that the end result of this project will not increase and likely serve to reduce current emission levels of air toxics, the project has agreed to complete the air toxics modeling analysis. To estimate the ambient air concentrations, each contaminant concentration is calculated at the stack, assuming peak loading conditions. The contaminant loading from the stack is then subjected to air dispersion modeling to simulate the effect of local meteorological conditions. The ambient concentration at hypothetical ground level receptors is then calculated and compared to the air quality screening levels as developed by the MDEQ. 6.4.1 TAC EMISSION RATES AND RESULTS The input parameter emission rate was a generic 1 lb/hr for each boiler; therefore, the model output is in units of micrograms per cubic meter (µg/m³) per lb/hr for each boiler. Tables 4, 5 and 6 present the maximum emission rates for each TAC. These emission rates are based on information from the USEPA’s Web FIRE database for each EUSGU. Sulfuric acid emissions are based on 0.7% of the sulfur in the fuel being converted to SO3 based on information from the USEPA AP-42, Chapter 1.1, and footnote b of Table 1.1-3. The SO3 is readily converted to sulfuric acid. Following is the chemical reaction for the conversion:


𝑆𝑆𝑆𝑆3 + 𝐻𝐻2𝑆𝑆

𝑦𝑦𝑦𝑦𝑦𝑦𝑦𝑦𝑦𝑦𝑠𝑠�⎯⎯� 𝐻𝐻2𝑆𝑆𝑆𝑆4

Therefore, one mole of SO3 yields one mole of H2SO4. Based on the molecular weight of SO3 of 80 lbs/lb-mole and the molecular weight of H2SO4 of 98 lbs/lb-mole, approximately 1.225 lbs of H2SO4 are formed for every lb of SO3. Using this ratio and the AP-42 emission factor of 0.7% of the sulfur-forming SO3, results in the following:

0.7 𝑦𝑦𝑙𝑙𝑠𝑠 𝑆𝑆𝑆𝑆3

100 𝑦𝑦𝑙𝑙𝑠𝑠 𝑆𝑆 𝑦𝑦𝑖𝑖 𝑓𝑓𝑓𝑓𝑦𝑦𝑦𝑦 𝑥𝑥

1.225 𝑦𝑦𝑙𝑙𝑠𝑠 𝐻𝐻2 𝑆𝑆𝑆𝑆4

1 𝑦𝑦𝑙𝑙 𝑆𝑆𝑆𝑆3= 0.00858

𝑦𝑦𝑙𝑙𝑠𝑠 𝐻𝐻2𝑆𝑆𝑆𝑆4

𝑦𝑦𝑙𝑙 𝑆𝑆 𝑦𝑦𝑖𝑖 𝑓𝑓𝑓𝑓𝑦𝑦𝑦𝑦

0.00858 lb H2SO4 / lb sulfur in fuel is used to determine the H2SO4 emissions from each EUSGU. The unitized model results are included as Table 12. A CD containing the electronic model input/output files is provided in Appendix 9. To estimate the actual Predicted Ambient Impacts (PAI) for each TAC (except carcinogenic PAHs), the model PAI was multiplied by the maximum emission rate in lb/hr, for each TAC, with the contributions from each TAC emission source summed to give a conservative combined impact for that TAC. As presented in Tables 13, the combined emission rate for the carcinogenic PAHs were estimated based on each PAHs relative potency compared to benzo(a)pyrene. To estimate the actual PAI for the seven carcinogenic PAHs, the model PAI was multiplied by the combined emission rate for the carcinogenic PAHs. As presented in Table 14, the dioxins and furans were also combined based on their toxic equivalency factor. As presented in Table 15, the PAIs for all TACs from the boilers are below the applicable air quality screening levels obtained from the MDEQ-AQD List of Screening Levels.


7.0 SUMMARY AND CONCLUSION We Energies has proposed the addition of the AQCSs described in this application to enhance its ability to comply with future air quality requirements, including NESHAPs in 40 CFR 63 Subpart UUUUU. The proposed project triggers PSD permitting requirements for CO; therefore, a full air quality impacts analysis and top-down BACT review were conducted for that pollutant. In addition, at the agency’s request, We Energies has completed air dispersion modeling to show the project does not exceed the short-term SILs for PM2.5, PM10 and SO2. In this permit application, We Energies also demonstrates that after the proposed changes are complete, the facility will not cause or contribute to an exceedance of the short-term NAAQS for NO2. To confirm accuracy of the past actual emissions to projected actual emissions analyses used to demonstrate the non-PSD applicability of all criteria pollutants (except CO), the facility will continue to maintain detailed records of emissions. Timing is critical to meet all future air pollution control requirements in accordance with the compliance deadlines specified in the various state and federal regulations as noted previously. Therefore, We Energies requests an expedited permit review and approval process for this application.

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NOTES: ,. REFERENCE DRAWING BACKGROUND INFOR~ATION IS BASED ON PRE EXISTING DATA HDR DOES NOT WARRANT THE ACCURACY OR COMPLETENESS OF ANY BACKGROUND INFORMATION PRESENT ON THEIR CONTRACT DOCUMENTS AND ASSUMES NO LIABILITY FOR THE DESIGN INFORMATION PRESENTED IN THE ABSENCE OF A COMPLETE, UP TO DATE CERTIFIED SITE SURVEY. UNCHARTED SERV1CES MAY EXIST AND ACTUAL LOCATIONS AND CONFIGURATIONS OF THE SERVICES AND SITE FEATURES MAY VARY FROM INFORMATION SHOWN ON DRAWINGS. THE CONTRACTOR SHALL BE RESPONSIBLE TO VERIFY AND VALIDATE DESIGN DATA AND ASSUMPTIONS PRESENTED ON THE CONTRACT DOCUMENTS. HDR SHALL BE NOTIFIED OR ANY DISCREPANCIES OR DEFICIENCIES BASED ON THE CONTRACTORS SURVEY

2. PAC SILO FOR S,6&7 SIZED FOR 24 TON CAPACITY PAC RATE ANTICIPATED TO BE NOMINALLY 75 L8/HR FOR ALL THREE UNITS.

3. EXISTING UNIT 7,8&9 PAC SYSTEM TO BE REUSED FOR ONLY 8-9 IN NEW CONFIGURATION.

4. DSI SILO FOR 8-9 SIZED FOR 150 TON CAPACITY. DSI FEED RATE ANTICIPATED TO BE APPROXIMATELY 1,600 LB/HR MAX TOTAL FOR BOTH UNITS.

5. EXISTING UNIT 5&:6 FABRIC FILTER ASH PIPING TO BE RE-ROUTED TO EXISTING UNIT 1-4 FABRIC FILTER ASH COLLECTION SYSTEM.

6. GRADE ELEVATIONS NOMINALLY 606' ASL.

7. ALL ELEVATIONS APPROXIMATED. FINAL EqUIPMENT SELECTION REQUIRED FOR FIRM VALUES.

REFERENCE DRAWINGS

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2. PAC SILO FOR 5,6&7 SIZED FOR 24 TON CAPACITY PAC RATE ANTICIPATED TO BE NOMINALLY 75 LBjHR FOR ALL THREE UNITS.

3. EXISTING UNIT 7,8&9 PAC SYSTEM TO BE REUSED FOR ONLY 8-9 IN NEW CONFIGURATION.

4. OSI SILO FOR B-9 SIZED FDR 150 TON CAPACITY. OSI FEED RATE ANTICIPATED TO BE APPROXIMATELY 1,600 LB/HR MAX TOTAL FOR Born UNITS.

5. EXISTING UNIT 5&:6 FABRIC FILTER ASH PIPING TO BE RE-ROUITO TO EXISTING UNIT 1-4 FABRIC FILTER ASH COLLECTlON SYSTEM.

6. GRADE ELEVATIONS NOMINALLY 606· ASL.


REFERENCE DRAWINGS

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390+-1-103 WHEElABRATOR AJR POLLUTlON CONTROL INC. GENERAL ARRANGEMENT SECTIONS.

1107-Q5-04A BCSI ACI INJ ECTION SYSTEM (BUDGETARY)


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NOTES: ,. REFERENCE DRAWING BACKGROUND INFOR~ATION IS BASED ON PRE EXISTING DATA HDR DOES NOT WARRANT THE ACCURACY OR COMPLETENESS OF ANY BACKGROUND INFORMATION PRESENT ON THEIR CONTRACT DOCU~ENTS AND ASSU~ES NO LIABILITY FOR THE DESIGN INFORMATION PRESENTED IN THE ABSENCE OF A CO~ PLETE , UP TO DATE CERTIFIED SITE SURVEY. UNCHMTED SERV1CES MAY EXIST AND ACTUAL LOCATIONS AND CONFIGURATIONS OF THE SERVICES AND SITE FEATURES MAY VARY FROM INFORMATION SHOWN ON DRAWINGS. THE CONTRACTOR SHALL BE RESPONSIBLE TO VERIFY AND VAlJDATE DESIGN DATA AND ASSUMPTIONS PRESENTED ON THE CONTRACT OOCUMENTS. HDR SHALL BE NOTIFIED OR AN'!' DISCREPANCIES OR DEFICIENCIES BASED ON THE CONTRACTORS SURVEY

2. PAC SILO FOR 5,6&7 SIZED FOR 24 TON CAPACITY PAC RATE ANTICIPATED TO BE NOMINALLY 75 L8/HR FOR ALL THREE UNITS.

3. EXISTING UNIT 7,8&9 PAC SYSTEM TO BE REUSED FOR ONLY B-9 IN NEW CONFIGURATION.

4. OSI SILO FOR B-9 SIZED FOR 150 TON CAPACITY. OSI FEED RATE ANTlCIPATED TO BE APPROXIMATELY 1,600 LB/HR MAX TOTAL FOR BOTH UNITS.

5. EXISTING UNIT 5&:6 FABRIC FILTER ASH PIPING TO BE RE-ROUITO TO EXISTING UNIT 1-4 FAERIC FILTER ASH COLLECTlON SYSTEM.

s. GRADE ELEYATIONS NOMINALLY SOS· ASL.


REFERENCE DRAWINGS

390+-1-101 WHEELABRATOR AJR POLLUTION CONTROL INC GENERAl. ARRANGEMENT.

3904-1-100 WHEELABRATOR AJR POLLUTION CONTROL INC. GENERAl. ARRANGEMENT

390+-1-103 WHEElABRATOR AJR POLLUTlON CONTROL INC. GENERAL ARRANGEMENT SECTIONS.

1107-Q5-04A BCSI ACI INJECTION SYSTEM (BUDGETARY)


REV DATE DESCRIPTION DWN ENGR CHI< APPV -........... --"-_ .... "'-",, ......... kII--."-"·"- _"..-._ • .-, • ..,-.

....-----... WOLVERINE "'" ,"'"'",,, waenergies e


FIGURE 2

SCALE: 1"= 150'


, .tt8H -V~O-'OOU'i ·ON ·,Mll

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c

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10 11

NOTES: , . REFEREN CE DRAWING BACKGROUND INFOR~ATION IS BASED ON PRE EXISTING DATA HDR DOES NOT WAR RANT THE ACCURACY OR COMPLETENESS OF ANY BACKGROUND INFORMATION PRESENT ON THEIR CON TRACT DOCU~ENTS AND ASSU~ES NO LIABILITY FOR THE DESIGN IN FORMATION PRESENTED IN THE ABSENCE OF A CO~ PLETE , UP TO DATE CERTIFIED SITE SURVEY. UNCHARTED SERV1 CES MAY EXIST AND ACTUAL LOCATIONS AND CONFIGURATIO NS OF THE SERVICES AND SITE FEATURES MAY VARY FROM INFORMATION SHOWN ON DRAWINGS. THE CONTRACTOR SHALL BE RESPONSI BLE TO VERIFY AND VAlJDATE DESIGN DATA AND ASSUMPTIONS PRESENTED ON THE CONTRACT OOCU MENTS. HDR SHALL BE NOTIFIED OR ANY DISCREPANCI ES OR DEFICIENCIES BASED ON THE CONTRACTORS SURVEY

2. PAC SILO FOR 5,6& 7 SIZED FOR 24 TON CAPACITY PAC RATE ANTICI PATED TO BE NOMINALLY 7 5 L8 / HR FOR ALL THREE UN ITS.

3 . EXISTING UN IT 7,8&9 PAC SYSTEM TO BE REUSED FOR ONLY 8-9 IN NEW CONFIGURATION.

4. DSI SILO FOR B-9 SIZED FOR 150 TON CAPACITY. DSI FEED RATE AN Tl CIPATED TO BE APPROXIMATELY 1,600 LB/ HR MAX TOTAL FOR BOTH UNITS.

5 . EXI STING UNIT 5 &: 6 FABRIC FILTER ASH PIPING TO BE RE- ROUITD TO EXISTING UNIT 1- 4 FAER IC FILTER ASH COLLECTlON SYSTEM.

6. GRADE ELEVATIONS NOMINAL LY 606· ASL.

7. ALL ELEVATIONS APPROXI MATED. FI NAL EQUI PMENT SELECTION REQUI RED FOR FIRM VALU ES.

REFERENCE DRAWI NGS

390 -4-- 1- 101 WHEELABRATO R AJ R POLLUTION CONTROL INC GENERAL ARRANGEMEN T.

3904-1-100 WHEELABRATOR AJ R POLLUTION CONTROL INC. GENERAL AR RA NGEM EN T

390 -4--1-1 0 3 WHEElABRATOR AJ R POLLUTl ON CONTROL INC. GENERAL ARRANGEMENT SECTIONS.

1107-05-04A BCSI ACI INJECTION SYSTEM ( BUDGETARY)


REV DATE DESCRIPTION DWN ENGR CHI< APPV - ........... --<1 __ .... "'-"<1111\. ....

kII--'''- ... ..- _11"- ._ . .-. . ..,-.

..-----.. WOLVERINE "'" """'",,, waenergies c::


FIGURE 2

SCALE: 1"= 150'



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>< 925 1000 1000 1000 50 1050 1050 1050 2 100 Mass Flow (KPPH) C 05 WAR ,

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B "JAN" A OPEN I OWN" R...,EW JHP AWS

>< I REV OATE , CHK lAPP.

Pre ssu re (inHG ) -0.5 -4. 75 -8.5 -11 -2 -6 -14 0.5 ·0.5 ::-:::.:: =' a::-

Temperature (OF) 1950 730 320 320 335 >< 165 165 180 180

lil'1 1. All values estimated . Not to be use d f or design .

2. SDA In le t Data (Point 51 e sti amted from plant stack data ta ken fro m 8/ 16/10 (Gro ss MW = 90, Stack Temp = 111.6 F. SCFH = 13.112.116)

F

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--------- C WOLVERINE w88nergies """ """'"'"

UNITS 5-6 AQCS RETROFIT G BITUt.4INOUS COAL

FLOW DIAGRAM FIGURE 3A

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Outlet Outlet Feed Inlet Inlet Dudet Inlet

>< 925 1000 1000 1000 50 1050 1050 1050 2100 Mass Flow (KPPH) C 05 '" , :::~ ~ ~ Volume Flow tKACFM) ;><:: 468 335.0 337 335 >< 280 28S 283 S6S

B "JAN" A OPEN I OWNER ',""EW JHP AWS

>< IRE' OATE , CHK lAP"

Pressure (inHG) -O.S -4. 75 -8. S -11 -2 -6 -14 O.S -0. 5 ::-:::.:: =' a::-

Temperature (OF) 1950 730 320 320 33S >< 16S 16S 180 180

lil'1 1. All values est imated. Not to be used for design .

2. SDA In let Data (Point 5) estiamted from plant stack data taken from 8/16/10 (Gross MW = 90, Stack Temp = 331.6 F, SCF H = 13,112,316)

F

3. Air heate r leakage assumed at 8% .

~ C WOLVERINE Mlsnergies """ """"'"

UNITS 5-6 AQCS RETROFIT G BITU~INOUS COAL

FLOW DIAGRAM FIGURE 3A


CONSTRUCTION owo. NO. 1 ~~OlA bEV. C

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B

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Volume Flow tKACFM) ;><:: 468 335.0 337

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1. All values estimated. Not to be used for design .

,

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2. SDA In let Data (Point 5) estiamted from plant stack data take n fro m 8/16/10 (Gross MW = 90, Stack Temp = 331.6 F, SCF H = 13.112.316)

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B

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Mlsnergies C UNITS 5-6 AOCS RETROFIT

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>< 458 328.0 330 330 270 265 263 525 , ''IN<'' AWS

Volume Flow (KACFM) A OPEN IOWNER R,""EW I JHP AWS

-ll .5 -4.75 -8. 5 -11 -2 >< -6 -10 0. 5 -0. 5 I REV OATE , I OWN EN .. CHK IAPP'I Pressure (inHG) : :;:::.: Temperature (·F) 1950 730 325 325 340 >< 165 165 180 180

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-------- C WOLVERINE w88nergies """ """'"'"

UNITS 5-6 AQCS RETROFIT G PR8 COAL

FLOW DIAGRAM FIGURE 38


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2 5 , 7 , 10 11


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lilt 1. Al l values est imated. Not to be used for design. 2. Air heater leakage assumed at 8%.

~ C WOLVERINE Mlsnergies """ """"'"

UNITS 5-6 AQCS RETROFIT G PR8 COAL



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Temperature (-F) 1950 730

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10 11

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WOLVERINE 1O'IQ{~t

Mlsnergies C UNITS 5-6 AQCS RETROFIT

PR8 COAL

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Mass Flow (KPPH) >< 1060 1060 1145 1145 51 11% 1150 1150

Volu me Flow (KACFMI :><: 490 490 386.5 385 :><: 320 312 310

Pressure OnHG) · 0.7 ·4.6 · 6 ·12 · 2 >< -6.6 ·12.6 ·1

Temperat ure ("'F) 1860 627 627 320 335 >< 166 166 179

1. All values estimated . Not to be used for des ign.

2. Air heater leakage assumed at 8%.

r \


10 11

8 16 JAN 13 OWNER REVIEW JHP AWS

A OPEN OWNER REVIEW

REV DATE DESCRIPTION DWN ENGR CHK APPY _~ __ " __ " __ ''''-'rtlllll,l ... .... __ .. __ .. __ ._-

~

WOLVERINE """"".,"""

wa energies e UNIT 7 AQCS RETROFIT

FLOW DIAGRAM

FIGURE 4

SCALE: NONE

DWG. NO. 178445-CGA-SKt.A02 bEV. 8

2

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A

B

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( S EE YEN DOR pRAWI NGS)

r

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3.1 ESPOutl.t 4.) 10 Fan Inl.t 5.' SDA Inlet 6.) Ume Slu", 7·10 ... 0 .... 8.1 Booster Fan 9., Booster Fan

Outlet Feed InI.t Inlet Outlot

MilS' Flow (KPPHI >< 1060 1060 1145 1145 51 1196 1150 1150

Volu me Flow (KACFM) >< 490 490 386.5 385 >< 320 312 310

Pressure OnHG) · 0.7 ·4.6 · 6 ·12 -2 >< -6.6 -12.6 -1

Tem perature (~) 1860 627 627 320 335 >< 166 166 179

1. All values estimated . Not to be used for des ign.

2. Ai r heater leakage assumed at 8%.

I I

1 [

.

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10 11


A OPEN OWNER REVIEW

REV DATE DESCRIPTION DWN ENGR CHK APPV _~ __ .. __ ., __ .... ~tllIII,l ... .... __ .. __ .. __ ._-

.....----... WOLVERINE ""","'"'",,, waenergies c:;

UNIT 7 AQCS RETROFIT FLOW DIAGRAM

FIGURE 4

SCALE: NONE

DWG. NO. 178445-CGA-SKtwt02 IoEV. 8

2 5 , 7 B 10 11

Wri~S-V~O-.tt8H ·ON .""" I

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Mass Flow (KPPH) >< 1060 1060 1145 1145 51 1196 1150 1150 B 16 JAN 13 OWNER REVIEW JHP AWS

Volume Flow (KACFM) >< 490 490 386.5 385 >< 320 312 310 A OPEN OWNER REVIEW

REV DATE DESCRIPTION DWN ENGR CHK APPY

Pressure OnHG) · 0. 7 ·4.6 · 6 ·12 -2 >< -6.6 -12.6 -1 - ~- -"-- " -_''''~'''IIII,I ... .... __ .. __ .. __ ._-

Temperature (~) 1860 627 627 320 335 >< 166 166 179 lilt 1. All values estimated. Notto be used for design. 2. Air heater leakage assumed at 8%.

.--------. e WOLVERINE waenergies ""","'"W,,,

UNIT 7 AQeS RETROFIT G FLOW DIAGRAM

FIGURE 4 NOT TO BE USED FOR

SCALE: NONE CONSTRUCTION DWG. NO. 178445-CGA-SKtwt02 bEV.8

2

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6.) Ume Slu",

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Mass Flow (KPPHI >< 1060 1060 1145 1145 51

Volu me Flow (KACFM) >< 490 490 386.5 385 >< Pressure OnHG) · 0. 7 ·4.6 · 6 ·12 -2 >< Temperature (~) 1860 627 627 320 335 >< 1. All values estimated. Notto be used for des ign. 2. Air heater leakage assumed at 8%.

7 B

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1196 1150 1150

320 312 310

-6. 6 -12.6 -1

166 166 179

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10 11


A OPEN OWNER REVIEW

REV DATE DESCRIPTION DWN ENGR CHK APPV

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Mas, Flaw (KPPHI >< 1060 1060 1145 1145 2290 2 2290 2290

>< >< , HI JAN 13 JHP AWS Volume Flow (KACFM) 490 490 395 395 790 771 766. 5 A OPEN OWNER REVIEW

>< REV "''' DESCRIPTION OWN ENGR eN. JJ'PV

Pressure (inHG) -0.7 -4. 6 -6 -12 -12 -3 -11 -0.9 --. .. .. __ <1 __ .. ...-- <1II1II,1 ... M, -......--.. ___ 11"'- _ --.--.

Temperature ("F) 1860 627 627 320 320 335 >< 320 335

lil~ L Al l values estimated. Not to be used for design.

2.. Air heate r leakage assumed at 8%.

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Mas, Flow IKPPHI >< 1060 1060 1145 1145 2290 2 2290 2290

>< >< , 16 JAN 13 JHP AWS Volume Flow (KACFM) 490 490 395 395 790 771 766.5 A OPEN OWNER REVIEW

>< REV OAT[ DESCRIPTION OWN ENGR eN. JJ''' Pressure (inHG)

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Tempe rature , -F) 1860 627 627 320 320 335 >< 320 335

lil~ 1. Al l values estimated. Not to be used fo r design. 2.. Ai r heater leakage assume d at 8%.

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Mas, Flow (KPPH) >< 1060 1060 1145 1145 2290 2 2290 2290

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>< REV OAT[ DESCRIPTION OWN ENGR CH' APPV

Pressure (inHG) -0.7 -4. 6 -6 -12 -12 -3 -11 -0.9 _ ......... __ <1 __ Il10...-- <1 II1II,1 ...

M, __ ..--. . .... __ 11"'- _ --.--.

Temperature , -F) 1860 627 627 320 320 335 >< 320 335

lil~ 1. Al l values estimated. Not to be used fo r design. 2.. Air heater leakage assumed at 8%.

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owe. NO. 178445-CGA-SKM03 I REV. B

Tables

Z:\2012\120697\WORK\Rept\PTI Application\NEW_April_WP_We_Emissions_2013_0304.xlsx 3/7/2013

Table 1 - Summary of New and Existing Emission UnitsAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Source Type Emission UnitOperational

StatusBoiler 5 ExistingBoiler 6 ExistingBoiler 7 ExistingBoiler 8 ExistingBoiler 9 ExistingUnits 1-4 Fly Ash Silo Bag Filter Vent ExistingUnits 7-9 TOXECON Powder Activated Carbon (PAC) Silo Vent Filter ExistingUnits 7-9 TOXECON Fly Ash Silo Bin Vent ExistingUnits 7-9 TOXECON Mechanical Exhauster Vents A and B ExistingFly Ash Storage Silos Baghouse Filter Vent ExistingNew PAC Silo Vent NewDSI Silo Vent NewPebble Lime Silo Vent NewUnits 1-4 Fly Ash Building, Telescopic Loading Chute for Dry Fly Ash ExistingUnits 7-9 TOXECON Ash Unloading Building Chute (Wet) ExistingFly Ash Storage Silos Loading and Unloading Facility ExistingUnit 1-4 Fly Ash ExistingUnit 7-9 Fly Ash (covered dump trucks and dry tanker trucks) ExistingActivated Carbon Delivery ExistingNew PAC Delivery NewDSI Delivery NewPebble Lime Delivery New

Paved Roads

Boilers

Fabric Filters

Ash Handling Transfers

of 1

Z:\2012\120697\WORK\Rept\PTI Application\NEW_2009_PIPP_Rolling_Avg_2013_0305.xlsx 3/6/2013

Table 2 - NSR Pollutant Baseline Emissions for BoilersAir Use Permit to Install AQCS

We Energies, Marquette, Michigan

Pollutant Boiler Emissions

(tpy)

Material Handling

Emissions(tpy)

24-Month Rolling Time Period End

Date M(YYYY)

Baseline Heat Input (MMBtu/yr)

Criteria PollutantsNOx 5,919.7 NA 32010 30,543,133 PM, filterable 92.8 0.75 32010 30,543,133 PM10 286.75 0.27 32010 30,543,133 PM2.5 286.75 0.14 32010 30,543,133 SO2 9,322.4 NA 32010 30,543,133 VOC 46.6 NA 32010 30,543,133 Greenhouse Gas EmissionsCO2 3,178,840 NACH4 31.0 NAN2O 23.1 NACO2e 3,186,659 NA 32010 30,543,133 OtherPb 0.323 NA 32010 30,543,133 HF 115.3 NA 32010 30,543,133 Sulfuric Acid 35.8 NA 52010 30,417,462

of 1

Table 3 - Past Actual to Projected Actual AnalysisAir Use Permit to Install AQCS Retrofit PIPP

Projected Heat Input all Boilers 35,100,000 MMBtu/yrCapable Heat Input all Boilers 38,880,799 MMBtu/yr

ASolid Fuel

(tpy)

BMaterial Handling

Emissions(tpy)

CTotal

Projected Actual

Emissions(tpy)

Baseline Boiler Heat

Input (MMBTU/Yr)

Excludable Heat Input

(MMBTU/Yr)

BaselineEmission

Factor(lb/MMBTU)

DSolid Fuel Excludable Emissions

(tpy)

Excludable Material Handling

(tpy)

ETOTAL

Excludable(tpy)

Boiler Baseline

Emissions(tpy)

Fugitive Baseline

Emissions(tpy)

F Baseline Emissions

(tpy)

Baseline Period Ending

(MYYYY)

G Emissions Increase

(tpy)

SignificanceThreshold

(tpy)NOX 4,388 NA 4,388 30,543,133 4,556,867 0.39 883.2 NA 883.2 5,919.7 NA 5,920 32010 (2,415.4) 40 PM (filt) 128 1.067 129 30,543,133 4,556,867 0.006 13.8 0.0212 13.87 92.8 0.0713 92.9 32010 22.4 25 PM10 337 0.905 338 30,543,133 4,556,867 0.019 42.8 0.0206 42.80 286.75 0.0680 286.8 32010 8.36 15 PM2.5 337 0.848 338 30,543,133 4,556,867 0.019 42.8 0.0201 42.80 286.75 0.0658 286.8 32010 8.30 10 SO2 4,221 NA 4,221 30,543,133 4,556,867 0.61 1,390.9 NA 1,390.85 9,322 NA 9,322 32010 (6,492.0) 40 VOC 52.5 NA 52.5 30,543,133 4,556,867 0.003 6.95 NA 6.95 46.6 NA 46.6 32010 (1.0) 40 CO2e 3,660,978 NA 3,660,978 30,543,133 4,556,867 208.2 474,265 NA 474,265 3,178,840 NA 3,178,840 32010 7,873 75,000 Lead 0.4 NA 0.4 30,543,133 4,556,867 2.1E-05 0.05 NA 0.05 0.3 NA 0.3 32010 (0.004) 0.6 HF (Fluorides) 40.7 NA 40.7 30,543,133 4,556,867 0.008 17.2 NA 17.2 115.3 NA 115.3 32010 (91.8) 3 H2SO4 39.7 NA 39.7 30,417,462 4,682,538 2.4E-03 5.51 NA 5.51 35.8 NA 35.8 52010 (1.6) 7

A Projected Actual Solid Fuel (tpy) = Heat Input from Solid Fuel (MMBTU/yr) X Emission Factor solid fuel (lb/MMBTU) / 2000 lb/tonB Projected Actual Emissions for Material Handling = PTE for new equipment and projected emissions for existing affected equipment. C Total Projected Actual Emissions (tpy) = A + BD Excludable = Heat Input in excess of Baseline Heat Input (MMBTU/yr) that is the result of demand growth X Emission Factor solid fuel (lb/MMBTU) / 2000 lb/tonE Total Excludable = D + Excludable Material HandlingF Baseline Emissions Highest 24-Month Annual Average Past Actual Emission Rate

Calculate Annual Emission Increase as follows :

Projected Actual Emissions (C) = A + B

Emissions Increase (G) = C - E - F

IncreaseBaseline

Pollutant


Projected Actual Emissions Excludable Emissions


of 4

Table 4 - Estimated Maximum Short-Term Pollutant Emissions of Boilers 5 and 6Air Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Heat Input Capacity 995 MMBtu/hr 680 MMBtu/hr 120 MMBtu/hrHigher heating Value 23.5 MMBtu/ton 18.5 MMBtu/ton 138,500 Btu/gal

Throughput 42 ton/hr 37 ton/hr 7,184 gphSulfur Content 0.9 wt% 0.9 wt% 0.5 wt%

Ash Content 9.5 wt% 5.0 wt%

Pollutants CAS SourceControl

Efficiency(%)

Short-Term Emissions

(lb/hr)Source

Control Efficiency

(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)Criteria Pollutants

CO 630-08-0 0.2 lb/Million Btus PSD BACT factor controlled 199 0.2 lb/Million Btus PSD BACT factor

controlled 136 0.2 lb/Million Btus PSD BACT 24.0 199

NOX 0.25 lb/Million Btus Target Rate factor controlled 249 0.25 lb/Million Btus Target Rate factor

controlled 170 0.25 lb/Million Btus Target Rate factor controlled 30.0 249

PM, filterable 0.030 lb/Million Btus 40 CFR 63 Subpart UUUUU

factor controlled 29.9 0.030 lb/Million Btus 40 CFR 63

Subpart UUUUUfactor

controlled 20.4 2.0 lb/1000 Gallons Web-fire 1.0 0.02 29.9

PM10, total (filterable+condensable) 0.024 lb/Million Btus Target Rate factor controlled 23.9 0.024 lb/Million Btus Target Rate factor


PM2.5, total (filterable+condensable) 0.024 lb/Million Btus Target Rate factor controlled 23.9 0.024 lb/Million Btus Target Rate factor


SO2 2025-88-4 0.08 lb/Million Btus Target Rate factor controlled 79.6 0.08 lb/Million Btus Target Rate factor

controlled 54.4 0.1 lb/Million Btus Target Rate 9.6 79.6

VOC 0.06 lb/Tons Web-fire 2.5 0.06 lb/Tons Web-fire 2.2 0.2 lb/1000 Gallons Web-fire 1.4 2.5

Greenhouse Gas Emissions

CO2 124-38-9 205.9 lb/Million Btus GHG RuleTable C-1 204,882 213.9 lb/Million Btus GHG Rule

Table C-1 145,447 163.1 lb/Million Btus GHG RuleTable C-1 19,566 204,882

CH4 74-82-8 0.024 lb/Million Btus GHG RuleTable C-2 24.1 0.024 lb/Million Btus GHG Rule

Table C-2 16.5 0.0 lb/Million Btus GHG RuleTable C-2 0.8 24.1

N2O 10024-97-2 0.004 lb/Million Btus GHG RuleTable C-2 3.5 0.004 lb/Million Btus GHG Rule

Table C-2 2.4 0.0 lb/Million Btus GHG RuleTable C-2 0.2 3.5

CO2e 207.5 lb/Million Btus GWP Equivalents 206,477 215.5 lb/Million Btus GWP Equivalents 146,537 163.6 lb/Million Btus GWP Equivalents 19,632 206,477

Toxic Air Contaminants

Ammonia 7664-41-7 0.6 lb/1000 Tons Web-fire 0.02 0.6 lb/1000 Tons Web-fire 0.02 0.8 lb/1000 Gallons Web-fire 5.7 5.75

HCl 7647-01-0 0.002 lb/Million Btus 40 CFR 63 Subpart UUUUU 2.0 0.0 lb/Million Btus 40 CFR 63

Subpart UUUUU 1.4 NA NA Web-fire 0.8 - 2.0

HF 7664-39-3 0.2 lb/Tons Web-fire 0.8 1.3 0.2 lb/Tons Web-fire 0.8 1.1 NA NA Web-fire 0.8 - 1.3

H2SO4 7664-93-9 0.2 lb/TonsCalculated based

on Fuel Sulfur input

0.8 1.3 0.2 lb/TonsCalculated based

on Fuel Sulfur input

0.8 1.1 0.0 NACalculated

based on Fuel Sulfur input

0.8 0.4 1.3

Organics

1,1,1-Trichloroethane 71-55-6 2.0E-05 lb/Tons Web-fire 8.5E-04 2.0E-05 lb/Tons Web-fire 7.4E-04 NA NA Web-fire 0.0E+00 8.5E-04

2,4-Dinitrotoluene 121-14-2 2.8E-07 lb/Tons Web-fire 1.2E-05 2.8E-07 lb/Tons Web-fire 1.0E-05 NA NA Web-fire 0.0E+00 1.2E-05

2-Chloroacetophenone 532-27-4 7.0E-06 lb/Tons Web-fire 3.0E-04 7.0E-06 lb/Tons Web-fire 2.6E-04 NA NA Web-fire 0.0E+00 3.0E-04

Acetaldehyde 75-07-0 5.7E-04 lb/Tons Web-fire 2.4E-02 5.7E-04 lb/Tons Web-fire 2.1E-02 NA NA Web-fire 0.0E+00 2.4E-02

Acetophenone 98-86-2 1.5E-05 lb/Tons Web-fire 6.4E-04 1.5E-05 lb/Tons Web-fire 5.5E-04 NA NA Web-fire 0.0E+00 6.4E-04

Acrolein 107-02-8 2.9E-04 lb/Tons Web-fire 1.2E-02 2.9E-04 lb/Tons Web-fire 1.1E-02 NA NA Web-fire 0.0E+00 1.2E-02

Benzene 71-43-2 1.3E-03 lb/Tons Web-fire 5.5E-02 1.3E-03 lb/Tons Web-fire 4.8E-02 NA NA Web-fire 0.0E+00 5.5E-02

Benzyl chloride 100-44-7 7.0E-04 lb/Tons Web-fire 3.0E-02 7.0E-04 lb/Tons Web-fire 2.6E-02 NA NA Web-fire 0.0E+00 3.0E-02

Bromoform 75-25-2 3.9E-05 lb/Tons Web-fire 1.7E-03 3.9E-05 lb/Tons Web-fire 1.4E-03 NA NA Web-fire 0.0E+00 1.7E-03

Bituminous Coal

Maximum Short-Term

Emissions Per Boiler(lb/hr)

Fuel Data Sub-Bituminous Coal Fuel Oil

Emission Factor Emission Factor Emission Factor


of 4






Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Bituminous Coal

Maximum Short-Term




Carbon sulfide 75-15-0 1.3E-04 lb/Tons Web-fire 5.5E-03 1.3E-04 lb/Tons Web-fire 4.8E-03 NA NA Web-fire 0.0E+00 5.5E-03

Chlorobenzene 108-90-7 2.2E-05 lb/Tons Web-fire 9.3E-04 2.2E-05 lb/Tons Web-fire 8.1E-04 NA NA Web-fire 0.0E+00 9.3E-04

Chloroform 67-66-3 5.9E-05 lb/Tons Web-fire 2.5E-03 5.9E-05 lb/Tons Web-fire 2.2E-03 NA NA Web-fire 0.0E+00 2.5E-03

Cyanide 57-12-5 2.5E-03 lb/Tons Web-fire 1.1E-01 2.5E-03 lb/Tons Web-fire 9.2E-02 NA NA Web-fire 0.0E+00 1.1E-01

Dichloromethane 75-09-2 2.9E-04 lb/Tons Web-fire 1.2E-02 2.9E-04 lb/Tons Web-fire 1.1E-02 NA NA Web-fire 0.0E+00 1.2E-02

Dimethyl sulfate 77-78-1 4.8E-05 lb/Tons Web-fire 2.0E-03 4.8E-05 lb/Tons Web-fire 1.8E-03 NA NA Web-fire 0.0E+00 2.0E-03

Dioctyl phthalate 117-81-7 7.3E-05 lb/Tons Web-fire 3.1E-03 7.3E-05 lb/Tons Web-fire 2.7E-03 NA NA Web-fire 0.0E+00 3.1E-03

Ethyl chloride 75-00-3 4.2E-05 lb/Tons Web-fire 1.8E-03 4.2E-05 lb/Tons Web-fire 1.5E-03 NA NA Web-fire 0.0E+00 1.8E-03

Ethylbenzene 100-41-4 9.4E-05 lb/Tons Web-fire 4.0E-03 9.4E-05 lb/Tons Web-fire 3.5E-03 NA NA Web-fire 0.0E+00 4.0E-03

Ethylene dibromide 106-93-4 1.2E-06 lb/Tons Web-fire 5.1E-05 1.2E-06 lb/Tons Web-fire 4.4E-05 NA NA Web-fire 0.0E+00 5.1E-05

Ethylene dichloride 107-06-2 4.0E-05 lb/Tons Web-fire 1.7E-03 4.0E-05 lb/Tons Web-fire 1.5E-03 NA NA Web-fire 0.0E+00 1.7E-03

Formaldehyde 50-00-0 2.4E-04 lb/Tons Web-fire 1.0E-02 2.4E-04 lb/Tons Web-fire 8.8E-03 6.1E-02 lb/1000 GallonsWebfire range

3.500E-2 - 6.100E-2

4.4E-01 4.4E-01

Isomers of xylene 1330-20-7 3.7E-05 lb/Tons Web-fire 1.6E-03 3.7E-05 lb/Tons Web-fire 1.4E-03 NA NA Web-fire 0.0E+00 1.6E-03

Isophorone 78-59-1 5.8E-04 lb/Tons Web-fire 2.5E-02 5.8E-04 lb/Tons Web-fire 2.1E-02 NA NA Web-fire 0.0E+00 2.5E-02

Isopropylbenzene 98-82-8 5.3E-06 lb/Tons Web-fire 2.2E-04 5.3E-06 lb/Tons Web-fire 1.9E-04 NA NA Web-fire 0.0E+00 2.2E-04

Methyl bromide 74-83-9 1.6E-04 lb/Tons Web-fire 6.8E-03 1.6E-04 lb/Tons Web-fire 5.9E-03 NA NA Web-fire 0.0E+00 6.8E-03

Methyl chloride 74-87-3 5.3E-04 lb/Tons Web-fire 2.2E-02 5.3E-04 lb/Tons Web-fire 1.9E-02 NA NA Web-fire 0.0E+00 2.2E-02

Methyl ethyl ketone 78-93-3 3.9E-04 lb/Tons Web-fire 1.7E-02 3.9E-04 lb/Tons Web-fire 1.4E-02 NA NA Web-fire 0.0E+00 1.7E-02

Methyl hydrazine 60-34-4 1.7E-04 lb/Tons Web-fire 7.2E-03 1.7E-04 lb/Tons Web-fire 6.2E-03 NA NA Web-fire 0.0E+00 7.2E-03

Methyl methacrylate 80-62-6 2.0E-05 lb/Tons Web-fire 8.5E-04 2.0E-05 lb/Tons Web-fire 7.4E-04 NA NA Web-fire 0.0E+00 8.5E-04

N-Hexane 110-54-3 6.7E-05 lb/Tons Web-fire 2.8E-03 6.7E-05 lb/Tons Web-fire 2.5E-03 NA NA Web-fire 0.0E+00 2.8E-03

Perchloroethylene 127-18-4 4.3E-05 lb/Tons Web-fire 1.8E-03 4.3E-05 lb/Tons Web-fire 1.6E-03 NA NA Web-fire 0.0E+00 1.8E-03

Phenol 108-95-2 1.6E-05 lb/Tons Web-fire 6.8E-04 1.6E-05 lb/Tons Web-fire 5.9E-04 NA NA Web-fire 0.0E+00 6.8E-04

Propionaldehyde 123-38-6 3.8E-04 lb/Tons Web-fire 1.6E-02 3.8E-04 lb/Tons Web-fire 1.4E-02 NA NA Web-fire 0.0E+00 1.6E-02

Pyrene 129-00-0 3.3E-07 lb/Tons Web-fire 1.4E-05 3.3E-07 lb/Tons Web-fire 1.2E-05 NA NA Web-fire 0.0E+00 1.4E-05

Styrene 100-42-5 2.5E-05 lb/Tons Web-fire 1.1E-03 2.5E-05 lb/Tons Web-fire 9.2E-04 NA NA Web-fire 0.0E+00 1.1E-03

Tert-butyl methyl ether 1634-04-4 3.5E-05 lb/Tons Web-fire 1.5E-03 3.5E-05 lb/Tons Web-fire 1.3E-03 NA NA Web-fire 0.0E+00 1.5E-03

Toluene 108-88-3 2.4E-04 lb/Tons Web-fire 1.0E-02 2.4E-04 lb/Tons Web-fire 8.8E-03 NA NA Web-fire 0.0E+00 1.0E-02


of 4






Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Bituminous Coal

Maximum Short-Term




Vinyl acetate 108-05-4 7.6E-06 lb/Tons Web-fire 3.2E-04 7.6E-06 lb/Tons Web-fire 2.8E-04 NA NA Web-fire 0.0E+00 3.2E-04

Metals

Antimony 7440-36-0 1.8E-05 lb/Tons Web-fire factor controlled 7.6E-04 1.8E-05 lb/Tons Web-fire factor

controlled 6.6E-04 NA NA 0.0E+00 7.6E-04

Arsenic 7440-38-2 4.1E-04 lb/Tons Web-fire factor controlled 1.7E-02 4.1E-04 lb/Tons Web-fire factor

controlled 1.5E-02 4.0E-06 lb/Million Btus Web-fire 1.0E+00 5.3E-07 1.7E-02

Beryllium 7440-41-7 2.1E-05 lb/Tons Web-fire factor controlled 8.9E-04 2.1E-05 lb/Tons Web-fire factor


Cadmium 7440-43-9 5.1E-05 lb/Tons Web-fire factor controlled 2.2E-03 5.1E-05 lb/Tons Web-fire factor


Chromium 7440-47-3 2.6E-04 lb/Tons Web-fire factor controlled 1.1E-02 2.6E-04 lb/Tons Web-fire factor


Chromium (VI) 18540-29-9 7.9E-05 lb/Tons Web-fire factor controlled 3.3E-03 7.9E-05 lb/Tons Web-fire factor


Cobalt 7440-48-4 1.0E-04 lb/Tons Web-fire factor controlled 4.2E-03 1.0E-04 lb/Tons Web-fire factor


Copper 7440-50-8 NA NA 0.0E+00 NA NA 0.0E+00 6.0E-06 lb/Million Btus Web-fire 1.0E+00 7.9E-07 7.9E-07

Pb 7439-92-1 4.2E-04 lb/Tons Web-fire factor controlled 1.8E-02 4.2E-04 lb/Tons Web-fire factor


Magnesium 7439-95-4 1.1E-02 lb/Tons Web-fire factor controlled 4.7E-01 1.1E-02 lb/Tons Web-fire factor


Manganese 7439-96-5 4.9E-04 lb/Tons Web-fire factor controlled 2.1E-02 4.9E-04 lb/Tons Web-fire factor


Mercury 7439-97-6 1.2E-06 lb/Million Btus 40 CFR 63 Subpart UUUUU

factor controlled 1.2E-03 1.2E-06 lb/Million Btus 40 CFR 63

Subpart UUUUUfactor


Nickel 7440-02-0 2.8E-04 lb/Tons Web-fire factor controlled 1.2E-02 2.8E-04 lb/Tons Web-fire factor


Selenium 7782-49-2 1.3E-03 lb/Tons Web-fire factor controlled 5.5E-02 1.3E-03 lb/Tons Web-fire factor


Zinc 7440-66-6 NA NA 0.0E+00 NA NA 0.0E+00 4.0E-06 lb/Million Btus Web-fire 1.0E+00 5.3E-07 5.3E-07

PAHs

5-Methyl Chrysene 3697-24-3 2.2E-08 lb/Tons Web-fire 9.3E-07 2.2E-08 lb/Tons Web-fire 8.1E-07 NA NA 0.0E+00 9.3E-07

Acenaphthene 83-32-9 5.1E-07 lb/Tons Web-fire 2.2E-05 5.1E-07 lb/Tons Web-fire 1.9E-05 NA NA 0.0E+00 2.2E-05

Acenaphthylene 208-96-8 2.5E-07 lb/Tons Web-fire 1.1E-05 2.5E-07 lb/Tons Web-fire 9.2E-06 NA NA 0.0E+00 1.1E-05

Anthracene 120-12-7 2.1E-07 lb/Tons Web-fire 8.9E-06 2.1E-07 lb/Tons Web-fire 7.7E-06 NA NA 0.0E+00 8.9E-06

Benzo (a) anthracene 56-55-3 8.0E-08 lb/Tons Web-fire 3.4E-06 8.0E-08 lb/Tons Web-fire 2.9E-06 9.4E-07 lb/1000 Gallons Web-fire 6.8E-06 6.8E-06

Benzo (a) pyrene 50-32-8 3.8E-08 lb/Tons Web-fire 1.6E-06 3.8E-08 lb/Tons Web-fire 1.4E-06 1.3E-06 lb/1000 Gallons Web-fire 9.6E-06 9.6E-06

Benzo (g,h,i) perylene 191-24-2 2.7E-08 lb/Tons Web-fire 1.1E-06 2.7E-08 lb/Tons Web-fire 9.9E-07 NA NA 0.0E+00 1.1E-06

Benzofluoranthenes 56832-73-6 1.1E-07 lb/Tons Web-fire 4.7E-06 1.1E-07 lb/Tons Web-fire 4.0E-06 NA NA 0.0E+00 4.7E-06

Biphenyl 92-52-4 1.7E-06 lb/Tons Web-fire 7.2E-05 1.7E-06 lb/Tons Web-fire 6.2E-05 NA NA 0.0E+00 7.2E-05

Chrysene 218-01-9 1.0E-07 lb/Tons Web-fire 4.2E-06 1.0E-07 lb/Tons Web-fire 3.7E-06 1.4E-06 lb/1000 Gallons Web-fire 1.0E-05 1.0E-05

Fluoranthene 206-44-0 7.1E-07 lb/Tons Web-fire 3.0E-05 7.1E-07 lb/Tons Web-fire 2.6E-05 2.8E-06 lb/1000 Gallons Web-fire 2.0E-05 3.0E-05


of 4






Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Bituminous Coal

Maximum Short-Term




Fluorene 86-73-7 9.1E-07 lb/Tons Web-fire 3.9E-05 9.1E-07 lb/Tons Web-fire 3.3E-05 NA NA 0.0E+00 3.9E-05

Indeno(1,2,3-cd)pyrene 193-39-5 6.1E-08 lb/Tons Web-fire 2.6E-06 6.1E-08 lb/Tons Web-fire 2.2E-06 NA NA 0.0E+00 2.6E-06

Naphthalene 91-20-3 1.3E-05 lb/Tons Web-fire 5.5E-04 1.3E-05 lb/Tons Web-fire 4.8E-04 3.3E-04 lb/1000 Gallons Web-fire 2.4E-03 2.4E-03

Phenanthrene 85-01-8 2.7E-06 lb/Tons Web-fire 1.1E-04 2.7E-06 lb/Tons Web-fire 9.9E-05 NA NA 0.0E+00 1.1E-04

Polycyclic organic matter (POM) 2.1E-06 lb/Million Btus Web-fire 2.1E-03 2.1E-06 lb/Million Btus Web-fire 1.4E-03 3.3E-03 lb/1000 Gallons Web-fire 2.4E-02 2.4E-02

Dioxins/Furans

2,3,7,8-Tetrachlorodibenzofuran 51207-31-9 5.1E-11 lb/Tons Web-fire factor controlled 2.2E-09 5.1E-11 lb/Tons Web-fire factor


2,3,7,8-Tetrachlorodibenzo-p-dioxin 1746-01-6 1.4E-11 lb/Tons Web-fire factor controlled 6.1E-10 1.4E-11 lb/Tons Web-fire factor


Heptachlorodibenzofurans, total 7.7E-11 lb/Tons Web-fire factor controlled 3.3E-09 7.7E-11 lb/Tons Web-fire factor


Heptachlorodibenzo-p-dioxins, total 37871-00-4 8.3E-11 lb/Tons Web-fire factor controlled 3.5E-09 8.3E-11 lb/Tons Web-fire factor


Hexachlorodibenzofurans, total 1.9E-10 lb/Tons Web-fire factor controlled 8.1E-09 1.9E-10 lb/Tons Web-fire factor


Hexachlorodibenzo-p-dioxins, total 34465-46-8 2.9E-11 lb/Tons Web-fire factor controlled 1.2E-09 2.9E-11 lb/Tons Web-fire factor


Octachlorodibenzofurans, total 39001-02-0 6.6E-11 lb/Tons Web-fire factor controlled 2.8E-09 6.6E-11 lb/Tons Web-fire factor


Octachlorodibenzo-p-dioxins, total 3268-87-9 4.2E-10 lb/Tons Web-fire factor controlled 1.8E-08 4.2E-10 lb/Tons Web-fire factor


Pentachlorodibenzofurans, total 30402-15-4 3.5E-10 lb/Tons Web-fire factor controlled 1.5E-08 3.5E-10 lb/Tons Web-fire factor


Pentachlorodibenzo-p-dioxins, total 4.5E-11 lb/Tons Web-fire factor controlled 1.9E-09 4.5E-11 lb/Tons Web-fire factor


Polychlorinated dibenzofurans, total 136677-10-6 1.1E-09 lb/Tons Web-fire factor controlled 4.6E-08 1.1E-09 lb/Tons Web-fire factor


Polychlorinated dibenzo-p-dioxins and furans, total 1.8E-09 lb/Tons Web-fire factor

controlled 7.5E-08 1.8E-09 lb/Tons Web-fire factor controlled 6.5E-08 NA NA 0.0E+00 7.5E-08

Polychlorinated dibenzo-p-dioxins, total 6.7E-10 lb/Tons Web-fire factor

controlled 2.8E-08 6.7E-10 lb/Tons Web-fire factor controlled 2.4E-08 NA NA 0.0E+00 2.8E-08

Tetrachlorodibenzofurans, total 4.0E-10 lb/Tons Web-fire factor controlled 1.7E-08 4.0E-10 lb/Tons Web-fire factor


Tetrachlorodibenzo-p-dioxins, total 9.3E-11 lb/Tons Web-fire factor controlled 3.9E-09 9.3E-11 lb/Tons Web-fire factor



of 6

Table 5 - Estimated Maximum Short-Term Pollutant Emissions of Boiler 7Air Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Heat Input Capacity 1010 MMBtu/hr 140.0 MMBtu/hrHigher heating Value 18.5 MMBtu/ton 138,500.0 Btu/gal

Throughput 55 ton/hr 1,011 gphSulfur Content 0.9 wt% 0.9 wt%

Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Criteria Pollutants


controlled 28.0 202


controlled 35.0 253

PM, filterable 0.03 lb/Million Btus 40 CFR 63 Subpart

factor controlled 30.3 2.0 lb/1000 Gallons Web-fire 1.0 0.00 30.3

PM10, total (filterable+condensable) 0.024 lb/Million Btus Target Rate factor controlled 24.2 2.3 lb/1000 Gallons Web-fire 1.0 0.003 24.2

PM2.5, total (filterable+condensable) 0.024 lb/Million Btus Target Rate factor controlled 24.2 1.6 lb/1000 Gallons Web-fire 1.0 0.002 24.2


controlled 11.2 80.8

VOC 0.06 lb/Tons Web-fire 3.3 0.2 lb/1000 Gallons Web-fire 0.2 3.3



Table C-1 22,828 216,031


Table C-2 0.9 24.5


Table C-2 0.2 3.6

CO2e 215.5 lb/Million Btus GWP Equivalents 217,650 163.6 lb/Million Btus GWP

Equivalents 22,904 217,650


Ammonia 7664-41-7 0.6 lb/1000 Tons Web-fire 0.03 0.8 lb/1000 Gallons Web-fire 0.8 0.81

HCl 7647-01-0 0.0 lb/Million Btus 40 CFR 63 Subpart 2.0 NA NA Web-fire 0.8 - 2.0

HF 7664-39-3 0.2 lb/Tons Web-fire 0.8 1.6 NA NA Web-fire 0.8 - 1.6

H2SO4 7664-93-9 0.2 lb/TonsCalculated




0.8 0.1 1.7

Fuel Data

Emission Factor Emission Factor

Sub-Bituminous Coal Fuel Oil

Maximum Short-Term

Emissions(lb/hr)


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data



Maximum Short-Term

Emissions(lb/hr)

Organics

1,1,1-Trichloroethane 71-55-6 2.0E-05 lb/Tons Web-fire 1.1E-03 NA NA Web-fire 0.0E+00 1.1E-03

2,4-Dinitrotoluene 121-14-2 2.8E-07 lb/Tons Web-fire 1.5E-05 NA NA Web-fire 0.0E+00 1.5E-05

2-Chloroacetophenone 532-27-4 7.0E-06 lb/Tons Web-fire 3.8E-04 NA NA Web-fire 0.0E+00 3.8E-04

Acetaldehyde 75-07-0 5.7E-04 lb/Tons Web-fire 3.1E-02 NA NA Web-fire 0.0E+00 3.1E-02

Acetophenone 98-86-2 1.5E-05 lb/Tons Web-fire 8.2E-04 NA NA Web-fire 0.0E+00 8.2E-04

Acrolein 107-02-8 2.9E-04 lb/Tons Web-fire 1.6E-02 NA NA Web-fire 0.0E+00 1.6E-02

Benzene 71-43-2 1.3E-03 lb/Tons Web-fire 7.1E-02 NA NA Web-fire 0.0E+00 7.1E-02

Benzyl chloride 100-44-7 7.0E-04 lb/Tons Web-fire 3.8E-02 NA NA Web-fire 0.0E+00 3.8E-02

Bromoform 75-25-2 3.9E-05 lb/Tons Web-fire 2.1E-03 NA NA Web-fire 0.0E+00 2.1E-03

Carbon sulfide 75-15-0 1.3E-04 lb/Tons Web-fire 7.1E-03 NA NA Web-fire 0.0E+00 7.1E-03

Chlorobenzene 108-90-7 2.2E-05 lb/Tons Web-fire 1.2E-03 NA NA Web-fire 0.0E+00 1.2E-03

Chloroform 67-66-3 5.9E-05 lb/Tons Web-fire 3.2E-03 NA NA Web-fire 0.0E+00 3.2E-03

Cyanide 57-12-5 2.5E-03 lb/Tons Web-fire 1.4E-01 NA NA Web-fire 0.0E+00 1.4E-01

Dichloromethane 75-09-2 2.9E-04 lb/Tons Web-fire 1.6E-02 NA NA Web-fire 0.0E+00 1.6E-02

Dimethyl sulfate 77-78-1 4.8E-05 lb/Tons Web-fire 2.6E-03 NA NA Web-fire 0.0E+00 2.6E-03

Dioctyl phthalate 117-81-7 7.3E-05 lb/Tons Web-fire 4.0E-03 NA NA Web-fire 0.0E+00 4.0E-03

Ethyl chloride 75-00-3 4.2E-05 lb/Tons Web-fire 2.3E-03 NA NA Web-fire 0.0E+00 2.3E-03

Ethylbenzene 100-41-4 9.4E-05 lb/Tons Web-fire 5.1E-03 NA NA Web-fire 0.0E+00 5.1E-03

Ethylene dibromide 106-93-4 1.2E-06 lb/Tons Web-fire 6.6E-05 NA NA Web-fire 0.0E+00 6.6E-05


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data



Maximum Short-Term

Emissions(lb/hr)

Ethylene dichloride 107-06-2 4.0E-05 lb/Tons Web-fire 2.2E-03 NA NA Web-fire 0.0E+00 2.2E-03

Formaldehyde 50-00-0 2.4E-04 lb/Tons Web-fire 1.3E-02 6.1E-02 lb/1000 GallonsWebfire range

3.500E-2 - 6.100E-2

6.2E-02 6.2E-02

Isomers of xylene 1330-20-7 3.7E-05 lb/Tons Web-fire 2.0E-03 NA NA Web-fire 0.0E+00 2.0E-03

Isophorone 78-59-1 5.8E-04 lb/Tons Web-fire 3.2E-02 NA NA Web-fire 0.0E+00 3.2E-02

Isopropylbenzene 98-82-8 5.3E-06 lb/Tons Web-fire 2.9E-04 NA NA Web-fire 0.0E+00 2.9E-04

Methyl bromide 74-83-9 1.6E-04 lb/Tons Web-fire 8.7E-03 NA NA Web-fire 0.0E+00 8.7E-03

Methyl chloride 74-87-3 5.3E-04 lb/Tons Web-fire 2.9E-02 NA NA Web-fire 0.0E+00 2.9E-02

Methyl ethyl ketone 78-93-3 3.9E-04 lb/Tons Web-fire 2.1E-02 NA NA Web-fire 0.0E+00 2.1E-02

Methyl hydrazine 60-34-4 1.7E-04 lb/Tons Web-fire 9.3E-03 NA NA Web-fire 0.0E+00 9.3E-03

Methyl methacrylate 80-62-6 2.0E-05 lb/Tons Web-fire 1.1E-03 NA NA Web-fire 0.0E+00 1.1E-03

N-Hexane 110-54-3 6.7E-05 lb/Tons Web-fire 3.7E-03 NA NA Web-fire 0.0E+00 3.7E-03

Perchloroethylene 127-18-4 4.3E-05 lb/Tons Web-fire 2.3E-03 NA NA Web-fire 0.0E+00 2.3E-03

Phenol 108-95-2 1.6E-05 lb/Tons Web-fire 8.7E-04 NA NA Web-fire 0.0E+00 8.7E-04

Propionaldehyde 123-38-6 3.8E-04 lb/Tons Web-fire 2.1E-02 NA NA Web-fire 0.0E+00 2.1E-02

Pyrene 129-00-0 3.3E-07 lb/Tons Web-fire 1.8E-05 NA NA Web-fire 0.0E+00 1.8E-05

Styrene 100-42-5 2.5E-05 lb/Tons Web-fire 1.4E-03 NA NA Web-fire 0.0E+00 1.4E-03


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data



Maximum Short-Term

Emissions(lb/hr)

Tert-butyl methyl ether 1634-04-4 3.5E-05 lb/Tons Web-fire 1.9E-03 NA NA Web-fire 0.0E+00 1.9E-03

Toluene 108-88-3 2.4E-04 lb/Tons Web-fire 1.3E-02 NA NA Web-fire 0.0E+00 1.3E-02

Vinyl acetate 108-05-4 7.6E-06 lb/Tons Web-fire 4.1E-04 NA NA Web-fire 0.0E+00 4.1E-04

Metals

Antimony 7440-36-0 1.8E-05 lb/Tons Web-fire factor controlled 9.8E-04 NA NA 0.0E+00 9.8E-04

Arsenic 7440-38-2 4.1E-04 lb/Tons Web-fire factor controlled 2.2E-02 4.0E-06 lb/Million Btus Web-fire 1.0E+00 6.7E-07 2.2E-02

Beryllium 7440-41-7 2.1E-05 lb/Tons Web-fire factor controlled 1.1E-03 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.1E-03

Cadmium 7440-43-9 5.1E-05 lb/Tons Web-fire factor controlled 2.8E-03 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 2.8E-03

Chromium 7440-47-3 2.6E-04 lb/Tons Web-fire factor controlled 1.4E-02 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.4E-02

Chromium (VI) 18540-29-9 7.9E-05 lb/Tons Web-fire factor controlled 4.3E-03 NA NA 0.0E+00 4.3E-03

Cobalt 7440-48-4 1.0E-04 lb/Tons Web-fire factor controlled 5.5E-03 NA NA 0.0E+00 5.5E-03

Copper 7440-50-8 NA NA 0.0E+00 6.0E-06 lb/Million Btus Web-fire 1.0E+00 1.0E-06 1.0E-06

Pb 7439-92-1 4.2E-04 lb/Tons Web-fire factor controlled

2.3E-02 9.0E-06 lb/Million Btus Web-fire 1.0E+00 1.5E-06 2.3E-02

Magnesium 7439-95-4 1.1E-02 lb/Tons Web-fire factor controlled 6.0E-01 NA NA 0.0E+00 6.0E-01

Manganese 7439-96-5 4.9E-04 lb/Tons Web-fire factor controlled 2.7E-02 6.0E-06 lb/Million Btus Web-fire 1.0E+00 1.0E-06 2.7E-02

Mercury 7439-97-6 1.2E-06 lb/Million Btus 40 CFR 63 Subpart

factor controlled 1.2E-03 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.2E-03

Nickel 7440-02-0 2.8E-04 lb/Tons Web-fire factor controlled 1.5E-02 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.5E-02

Selenium 7782-49-2 1.3E-03 lb/Tons Web-fire factor controlled 7.1E-02 1.5E-05 lb/Million Btus Web-fire 1.0E+00 2.5E-06 7.1E-02

Zinc 7440-66-6 NA NA 0.0E+00 4.0E-06 lb/Million Btus Web-fire 1.0E+00 6.7E-07 6.7E-07


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data



Maximum Short-Term

Emissions(lb/hr)

PAHs

5-Methyl Chrysene 3697-24-3 2.2E-08 lb/Tons Web-fire 1.2E-06 NA NA 0.0E+00 1.2E-06

Acenaphthene 83-32-9 5.1E-07 lb/Tons Web-fire 2.8E-05 NA NA 0.0E+00 2.8E-05

Acenaphthylene 208-96-8 2.5E-07 lb/Tons Web-fire 1.4E-05 NA NA 0.0E+00 1.4E-05

Anthracene 120-12-7 2.1E-07 lb/Tons Web-fire 1.1E-05 NA NA 0.0E+00 1.1E-05

Benzo (a) anthracene 56-55-3 8.0E-08 lb/Tons Web-fire 4.4E-06 9.4E-07 lb/1000 Gallons Web-fire 9.5E-07 4.4E-06

Benzo (a) pyrene 50-32-8 3.8E-08 lb/Tons Web-fire 2.1E-06 1.3E-06 lb/1000 Gallons Web-fire 1.4E-06 2.1E-06

Benzo (g,h,i) perylene 191-24-2 2.7E-08 lb/Tons Web-fire 1.5E-06 NA NA 0.0E+00 1.5E-06

Benzofluoranthenes 56832-73-6 1.1E-07 lb/Tons Web-fire 6.0E-06 NA NA 0.0E+00 6.0E-06

Biphenyl 92-52-4 1.7E-06 lb/Tons Web-fire 9.3E-05 NA NA 0.0E+00 9.3E-05

Chrysene 218-01-9 1.0E-07 lb/Tons Web-fire 5.5E-06 1.4E-06 lb/1000 Gallons Web-fire 1.4E-06 5.5E-06

Fluoranthene 206-44-0 7.1E-07 lb/Tons Web-fire 3.9E-05 2.8E-06 lb/1000 Gallons Web-fire 2.8E-06 3.9E-05

Fluorene 86-73-7 9.1E-07 lb/Tons Web-fire 5.0E-05 NA NA 0.0E+00 5.0E-05

Indeno(1,2,3-cd)pyrene 193-39-5 6.1E-08 lb/Tons Web-fire 3.3E-06 NA NA 0.0E+00 3.3E-06

Naphthalene 91-20-3 1.3E-05 lb/Tons Web-fire 7.1E-04 3.3E-04 lb/1000 Gallons Web-fire 3.4E-04 7.1E-04

Phenanthrene 85-01-8 2.7E-06 lb/Tons Web-fire 1.5E-04 NA NA 0.0E+00 1.5E-04

Polycyclic organic matter (POM) 2.1E-06 lb/Million Btus Web-fire 2.1E-03 3.3E-03 lb/1000 Gallons Web-fire 3.3E-03 3.3E-03


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data



Maximum Short-Term

Emissions(lb/hr)

Dioxins/Furans

2,3,7,8-Tetrachlorodibenzofuran 51207-31-9 5.1E-11 lb/Tons Web-fire factor controlled 2.8E-09 NA NA 0.0E+00 2.8E-09

2,3,7,8-Tetrachlorodibenzo-p-dioxin 1746-01-6 1.4E-11 lb/Tons Web-fire factor controlled 7.8E-10 NA NA 0.0E+00 7.8E-10

Heptachlorodibenzofurans, total 7.7E-11 lb/Tons Web-fire factor controlled 4.2E-09 NA NA 0.0E+00 4.2E-09

Heptachlorodibenzo-p-dioxins, total 37871-00-4 8.3E-11 lb/Tons Web-fire factor controlled 4.6E-09 NA NA 0.0E+00 4.6E-09

Hexachlorodibenzofurans, total 1.9E-10 lb/Tons Web-fire factor controlled 1.0E-08 NA NA 0.0E+00 1.0E-08

Hexachlorodibenzo-p-dioxins, total 34465-46-8 2.9E-11 lb/Tons Web-fire factor controlled 1.6E-09 NA NA 0.0E+00 1.6E-09

Octachlorodibenzofurans, total 39001-02-0 6.6E-11 lb/Tons Web-fire factor controlled 3.6E-09 NA NA 0.0E+00 3.6E-09

Octachlorodibenzo-p-dioxins, total 3268-87-9 4.2E-10 lb/Tons Web-fire factor controlled 2.3E-08 NA NA 0.0E+00 2.3E-08

Pentachlorodibenzofurans, total 30402-15-4 3.5E-10 lb/Tons Web-fire factor controlled 1.9E-08 NA NA 0.0E+00 1.9E-08

Pentachlorodibenzo-p-dioxins, total 4.5E-11 lb/Tons Web-fire factor controlled 2.4E-09 NA NA 0.0E+00 2.4E-09

Polychlorinated dibenzofurans, total 136677-10-6 1.1E-09 lb/Tons Web-fire factor controlled 6.0E-08 NA NA 0.0E+00 6.0E-08





Tetrachlorodibenzofurans, total 4.0E-10 lb/Tons Web-fire factor controlled 2.2E-08 NA NA 0.0E+00 2.2E-08

Tetrachlorodibenzo-p-dioxins, total 9.3E-11 lb/Tons Web-fire factor controlled 5.1E-09 NA NA 0.0E+00 5.1E-09


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Criteria Pollutants


controlled 28.0 202


controlled 35.0 253

PM, filterable 0.03 lb/Million Btus 40 CFR 63 Subpart UUUUU

factor controlled 30.3 0.03 lb/Million Btus ROP Limit factor


PM10, total (filterable+condensable) 0.024 lb/Million Btus Target Rate factor controlled 24.2 2.3 lb/1000 Gallons Web-fire 1.0 0.003 24.2

PM2.5, total (filterable+condensable) 0.024 lb/Million Btus Target Rate factor controlled 24.2 1.6 lb/1000 Gallons Web-fire 1.0 0.002 24.2



VOC 0.06 lb/Tons Web-fire 3.3 0.2 lb/1000 Gallons Web-fire 0.2 3.3



Table C-1 22,828 216,031


Table C-2 0.9 24.5


Table C-2 0.2 3.6

CO2e 215.5 lb/Million Btus GWP Equivalents 217,650 163.6 lb/Million Btus GWP

Equivalents 22,904 217,650


Ammonia 7664-41-7 0.6 lb/1000 Tons Web-fire 0.03 0.8 lb/1000 Gallons Web-fire 0.8 0.81

HCl 7647-01-0 0.0 lb/Million Btus 40 CFR 63 Subpart UUUUU 2.0 NA NA Web-fire 0.6 - 2.0

HF 7664-39-3 0.2 lb/Tons Web-fire 0.6 3.3 NA NA Web-fire 0.6 - 3.3

H2SO4 7664-93-9 0.2 lb/TonsCalculated




0.6 0.1 3.4

Fuel Data



Maximum Short-Term Emissions Per Boiler

(lb/hr)


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data




(lb/hr)

Organics

1,1,1-Trichloroethane 71-55-6 2.0E-05 lb/Tons Web-fire 1.1E-03 NA NA Web-fire 0.0E+00 1.1E-03

2,4-Dinitrotoluene 121-14-2 2.8E-07 lb/Tons Web-fire 1.5E-05 NA NA Web-fire 0.0E+00 1.5E-05

2-Chloroacetophenone 532-27-4 7.0E-06 lb/Tons Web-fire 3.8E-04 NA NA Web-fire 0.0E+00 3.8E-04

Acetaldehyde 75-07-0 5.7E-04 lb/Tons Web-fire 3.1E-02 NA NA Web-fire 0.0E+00 3.1E-02

Acetophenone 98-86-2 1.5E-05 lb/Tons Web-fire 8.2E-04 NA NA Web-fire 0.0E+00 8.2E-04

Acrolein 107-02-8 2.9E-04 lb/Tons Web-fire 1.6E-02 NA NA Web-fire 0.0E+00 1.6E-02

Benzene 71-43-2 1.3E-03 lb/Tons Web-fire 7.1E-02 NA NA Web-fire 0.0E+00 7.1E-02

Benzyl chloride 100-44-7 7.0E-04 lb/Tons Web-fire 3.8E-02 NA NA Web-fire 0.0E+00 3.8E-02

Bromoform 75-25-2 3.9E-05 lb/Tons Web-fire 2.1E-03 NA NA Web-fire 0.0E+00 2.1E-03

Carbon sulfide 75-15-0 1.3E-04 lb/Tons Web-fire 7.1E-03 NA NA Web-fire 0.0E+00 7.1E-03

Chlorobenzene 108-90-7 2.2E-05 lb/Tons Web-fire 1.2E-03 NA NA Web-fire 0.0E+00 1.2E-03

Chloroform 67-66-3 5.9E-05 lb/Tons Web-fire 3.2E-03 NA NA Web-fire 0.0E+00 3.2E-03

Cyanide 57-12-5 2.5E-03 lb/Tons Web-fire 1.4E-01 NA NA Web-fire 0.0E+00 1.4E-01

Dichloromethane 75-09-2 2.9E-04 lb/Tons Web-fire 1.6E-02 NA NA Web-fire 0.0E+00 1.6E-02

Dimethyl sulfate 77-78-1 4.8E-05 lb/Tons Web-fire 2.6E-03 NA NA Web-fire 0.0E+00 2.6E-03

Dioctyl phthalate 117-81-7 7.3E-05 lb/Tons Web-fire 4.0E-03 NA NA Web-fire 0.0E+00 4.0E-03

Ethyl chloride 75-00-3 4.2E-05 lb/Tons Web-fire 2.3E-03 NA NA Web-fire 0.0E+00 2.3E-03

Ethylbenzene 100-41-4 9.4E-05 lb/Tons Web-fire 5.1E-03 NA NA Web-fire 0.0E+00 5.1E-03

Ethylene dibromide 106-93-4 1.2E-06 lb/Tons Web-fire 6.6E-05 NA NA Web-fire 0.0E+00 6.6E-05


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data




(lb/hr)

Ethylene dichloride 107-06-2 4.0E-05 lb/Tons Web-fire 2.2E-03 NA NA Web-fire 0.0E+00 2.2E-03

Formaldehyde 50-00-0 2.4E-04 lb/Tons Web-fire 1.3E-02 6.1E-02 lb/1000 GallonsWebfire range

3.500E-2 - 6.100E-2

6.2E-02 6.2E-02

Isomers of xylene 1330-20-7 3.7E-05 lb/Tons Web-fire 2.0E-03 NA NA Web-fire 0.0E+00 2.0E-03

Isophorone 78-59-1 5.8E-04 lb/Tons Web-fire 3.2E-02 NA NA Web-fire 0.0E+00 3.2E-02

Isopropylbenzene 98-82-8 5.3E-06 lb/Tons Web-fire 2.9E-04 NA NA Web-fire 0.0E+00 2.9E-04

Methyl bromide 74-83-9 1.6E-04 lb/Tons Web-fire 8.7E-03 NA NA Web-fire 0.0E+00 8.7E-03

Methyl chloride 74-87-3 5.3E-04 lb/Tons Web-fire 2.9E-02 NA NA Web-fire 0.0E+00 2.9E-02

Methyl ethyl ketone 78-93-3 3.9E-04 lb/Tons Web-fire 2.1E-02 NA NA Web-fire 0.0E+00 2.1E-02

Methyl hydrazine 60-34-4 1.7E-04 lb/Tons Web-fire 9.3E-03 NA NA Web-fire 0.0E+00 9.3E-03

Methyl methacrylate 80-62-6 2.0E-05 lb/Tons Web-fire 1.1E-03 NA NA Web-fire 0.0E+00 1.1E-03

N-Hexane 110-54-3 6.7E-05 lb/Tons Web-fire 3.7E-03 NA NA Web-fire 0.0E+00 3.7E-03

Perchloroethylene 127-18-4 4.3E-05 lb/Tons Web-fire 2.3E-03 NA NA Web-fire 0.0E+00 2.3E-03

Phenol 108-95-2 1.6E-05 lb/Tons Web-fire 8.7E-04 NA NA Web-fire 0.0E+00 8.7E-04

Propionaldehyde 123-38-6 3.8E-04 lb/Tons Web-fire 2.1E-02 NA NA Web-fire 0.0E+00 2.1E-02

Pyrene 129-00-0 3.3E-07 lb/Tons Web-fire 1.8E-05 NA NA Web-fire 0.0E+00 1.8E-05

Styrene 100-42-5 2.5E-05 lb/Tons Web-fire 1.4E-03 NA NA Web-fire 0.0E+00 1.4E-03

Tert-butyl methyl ether 1634-04-4 3.5E-05 lb/Tons Web-fire 1.9E-03 NA NA Web-fire 0.0E+00 1.9E-03

Toluene 108-88-3 2.4E-04 lb/Tons Web-fire 1.3E-02 NA NA Web-fire 0.0E+00 1.3E-02

Vinyl acetate 108-05-4 7.6E-06 lb/Tons Web-fire 4.1E-04 NA NA Web-fire 0.0E+00 4.1E-04


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data




(lb/hr)

Metals

Antimony 7440-36-0 1.8E-05 lb/Tons Web-fire factor controlled 9.8E-04 NA NA 0.0E+00 9.8E-04

Arsenic 7440-38-2 4.1E-04 lb/Tons Web-fire factor controlled 2.2E-02 4.0E-06 lb/Million Btus Web-fire 1.0E+00 6.7E-07 2.2E-02

Beryllium 7440-41-7 2.1E-05 lb/Tons Web-fire factor controlled 1.1E-03 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.1E-03

Cadmium 7440-43-9 5.1E-05 lb/Tons Web-fire factor controlled 2.8E-03 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 2.8E-03

Chromium 7440-47-3 2.6E-04 lb/Tons Web-fire factor controlled 1.4E-02 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.4E-02

Chromium (VI) 18540-29-9 7.9E-05 lb/Tons Web-fire factor controlled 4.3E-03 NA NA 0.0E+00 4.3E-03

Cobalt 7440-48-4 1.0E-04 lb/Tons Web-fire factor controlled 5.5E-03 NA NA 0.0E+00 5.5E-03

Copper 7440-50-8 NA NA 0.0E+00 6.0E-06 lb/Million Btus Web-fire 1.0E+00 1.0E-06 1.0E-06

Pb 7439-92-1 4.2E-04 lb/Tons Web-fire factor controlled 2.3E-02 9.0E-06 lb/Million Btus Web-fire 1.0E+00 1.5E-06 2.3E-02

Magnesium 7439-95-4 1.1E-02 lb/Tons Web-fire factor controlled 6.0E-01 NA NA 0.0E+00 6.0E-01

Manganese 7439-96-5 4.9E-04 lb/Tons Web-fire factor controlled 2.7E-02 6.0E-06 lb/Million Btus Web-fire 1.0E+00 1.0E-06 2.7E-02

Mercury 7439-97-6 1.2E-06 lb/Million Btus 40 CFR 63 Subpart UUUUU

factor controlled 1.2E-03 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.2E-03

Nickel 7440-02-0 2.8E-04 lb/Tons Web-fire factor controlled 1.5E-02 3.0E-06 lb/Million Btus Web-fire 1.0E+00 5.0E-07 1.5E-02

Selenium 7782-49-2 1.3E-03 lb/Tons Web-fire factor controlled 7.1E-02 1.5E-05 lb/Million Btus Web-fire 1.0E+00 2.5E-06 7.1E-02

Zinc 7440-66-6 NA NA 0.0E+00 4.0E-06 lb/Million Btus Web-fire 1.0E+00 6.7E-07 6.7E-07

PAHs

5-Methyl Chrysene 3697-24-3 2.2E-08 lb/Tons Web-fire 1.2E-06 NA NA 0.0E+00 1.2E-06

Acenaphthene 83-32-9 5.1E-07 lb/Tons Web-fire 2.8E-05 NA NA 0.0E+00 2.8E-05

Acenaphthylene 208-96-8 2.5E-07 lb/Tons Web-fire 1.4E-05 NA NA 0.0E+00 1.4E-05


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data




(lb/hr)

Anthracene 120-12-7 2.1E-07 lb/Tons Web-fire 1.1E-05 NA NA 0.0E+00 1.1E-05

Benzo (a) anthracene 56-55-3 8.0E-08 lb/Tons Web-fire 4.4E-06 9.4E-07 lb/1000 Gallons Web-fire 9.5E-07 4.4E-06

Benzo (a) pyrene 50-32-8 3.8E-08 lb/Tons Web-fire 2.1E-06 1.3E-06 lb/1000 Gallons Web-fire 1.4E-06 2.1E-06

Benzo (g,h,i) perylene 191-24-2 2.7E-08 lb/Tons Web-fire 1.5E-06 NA NA 0.0E+00 1.5E-06

Benzofluoranthenes 56832-73-6 1.1E-07 lb/Tons Web-fire 6.0E-06 NA NA 0.0E+00 6.0E-06

Biphenyl 92-52-4 1.7E-06 lb/Tons Web-fire 9.3E-05 NA NA 0.0E+00 9.3E-05

Chrysene 218-01-9 1.0E-07 lb/Tons Web-fire 5.5E-06 1.4E-06 lb/1000 Gallons Web-fire 1.4E-06 5.5E-06

Fluoranthene 206-44-0 7.1E-07 lb/Tons Web-fire 3.9E-05 2.8E-06 lb/1000 Gallons Web-fire 2.8E-06 3.9E-05

Fluorene 86-73-7 9.1E-07 lb/Tons Web-fire 5.0E-05 NA NA 0.0E+00 5.0E-05

Indeno(1,2,3-cd)pyrene 193-39-5 6.1E-08 lb/Tons Web-fire 3.3E-06 NA NA 0.0E+00 3.3E-06

Naphthalene 91-20-3 1.3E-05 lb/Tons Web-fire 7.1E-04 3.3E-04 lb/1000 Gallons Web-fire 3.4E-04 7.1E-04

Phenanthrene 85-01-8 2.7E-06 lb/Tons Web-fire 1.5E-04 NA NA 0.0E+00 1.5E-04

Polycyclic organic matter (POM) 2.1E-06 lb/Million Btus Web-fire 2.1E-03 3.3E-03 lb/1000 Gallons Web-fire 3.3E-03 3.3E-03


of 6




Ash Content 5.0 wt%


Efficiency(%)


(lb/hr)Source

Control Efficiency

(%)


(lb/hr)

Fuel Data




(lb/hr)

Dioxins/Furans

2,3,7,8-Tetrachlorodibenzofuran 51207-31-9 5.1E-11 lb/Tons Web-fire factor controlled 2.8E-09 NA NA 0.0E+00 2.8E-09

2,3,7,8-Tetrachlorodibenzo-p-dioxin 1746-01-6 1.4E-11 lb/Tons Web-fire factor controlled 7.8E-10 NA NA 0.0E+00 7.8E-10

Heptachlorodibenzofurans, total 7.7E-11 lb/Tons Web-fire factor controlled 4.2E-09 NA NA 0.0E+00 4.2E-09

Heptachlorodibenzo-p-dioxins, total 37871-00-4 8.3E-11 lb/Tons Web-fire factor controlled 4.6E-09 NA NA 0.0E+00 4.6E-09

Hexachlorodibenzofurans, total 1.9E-10 lb/Tons Web-fire factor controlled 1.0E-08 NA NA 0.0E+00 1.0E-08

Hexachlorodibenzo-p-dioxins, total 34465-46-8 2.9E-11 lb/Tons Web-fire factor controlled 1.6E-09 NA NA 0.0E+00 1.6E-09

Octachlorodibenzofurans, total 39001-02-0 6.6E-11 lb/Tons Web-fire factor controlled 3.6E-09 NA NA 0.0E+00 3.6E-09

Octachlorodibenzo-p-dioxins, total 3268-87-9 4.2E-10 lb/Tons Web-fire factor controlled 2.3E-08 NA NA 0.0E+00 2.3E-08

Pentachlorodibenzofurans, total 30402-15-4 3.5E-10 lb/Tons Web-fire factor controlled 1.9E-08 NA NA 0.0E+00 1.9E-08

Pentachlorodibenzo-p-dioxins, total 4.5E-11 lb/Tons Web-fire factor controlled 2.4E-09 NA NA 0.0E+00 2.4E-09

Polychlorinated dibenzofurans, total 136677-10-6 1.1E-09 lb/Tons Web-fire factor controlled 6.0E-08 NA NA 0.0E+00 6.0E-08





Tetrachlorodibenzofurans, total 4.0E-10 lb/Tons Web-fire factor controlled 2.2E-08 NA NA 0.0E+00 2.2E-08

Tetrachlorodibenzo-p-dioxins, total 9.3E-11 lb/Tons Web-fire factor controlled 5.1E-09 NA NA 0.0E+00 5.1E-09


Table 7 - Total HAP Emissions for ProjectAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Max Emissions(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)


Annual Emissions

(tpy)Hazardous Air PollutantsHydrogen chloride 7647-01-0 1.99 6.29 1.99 6.49 2.02 7.09 2.02 7.52 2.02 7.70 10.04 35.10Hydrogen fluoride 7664-39-3 1.27 4.02 1.27 4.14 1.64 5.75 3.28 12.20 3.28 12.49 10.73 38.60Organics1,1,1-Trichloroethane 71-55-6 8.47E-04 2.68E-03 8.47E-04 2.76E-03 1.09E-03 3.83E-03 1.09E-03 4.07E-03 1.09E-03 4.16E-03 4.97E-03 0.022,4-Dinitrotoluene 121-14-2 1.19E-05 3.75E-05 1.19E-05 3.86E-05 1.53E-05 5.37E-05 1.53E-05 5.69E-05 1.53E-05 5.83E-05 6.96E-05 2.45E-042-Chloroacetophenone 532-27-4 2.96E-04 9.37E-04 2.96E-04 9.66E-04 3.82E-04 1.34E-03 3.82E-04 1.42E-03 3.82E-04 1.46E-03 1.74E-03 6.13E-03Acetaldehyde 75-07-0 0.02 0.08 0.02 0.08 0.03 0.11 0.03 0.12 0.03 0.12 0.14 0.50Acetophenone 98-86-2 6.35E-04 2.01E-03 6.35E-04 2.07E-03 8.19E-04 2.88E-03 8.19E-04 3.05E-03 8.19E-04 3.12E-03 3.73E-03 0.01Acrolein 107-02-8 0.01 0.04 0.01 0.04 0.02 0.06 0.02 0.06 0.02 0.06 0.07 0.25Benzene 71-43-2 0.06 0.17 0.06 0.18 0.07 0.25 0.07 0.26 0.07 0.27 0.32 1.14Benzyl chloride 100-44-7 0.03 0.09 0.03 0.10 0.04 0.13 0.04 0.14 0.04 0.15 0.17 0.61Bromoform 75-25-2 - -Carbon sulfide 75-15-0 5.50E-03 0.02 5.50E-03 0.02 7.10E-03 0.02 7.10E-03 0.03 7.10E-03 0.03 0.03 0.11Chlorobenzene 108-90-7 9.31E-04 2.95E-03 9.31E-04 3.04E-03 1.20E-03 4.22E-03 1.20E-03 4.47E-03 1.20E-03 4.58E-03 5.47E-03 0.02Chloroform 67-66-3 2.50E-03 7.90E-03 2.50E-03 8.14E-03 3.22E-03 0.01 3.22E-03 0.01 3.22E-03 0.01 0.01 0.05Cyanide 57-12-5 0.11 0.33 0.11 0.34 0.14 0.48 0.14 0.51 0.14 0.52 0.62 2.19Dichloromethane 75-09-2 0.01 0.04 0.01 0.04 0.02 0.06 0.02 0.06 0.02 0.06 0.07 0.25Dimethyl sulfate 77-78-1 2.03E-03 6.43E-03 2.03E-03 6.62E-03 2.62E-03 9.20E-03 2.62E-03 9.76E-03 2.62E-03 9.99E-03 0.01 0.04Dioctyl phthalate 117-81-7 3.09E-03 9.77E-03 3.09E-03 0.01 3.99E-03 0.01 3.99E-03 0.01 3.99E-03 0.02 0.02 0.06Ethyl chloride 75-00-3 1.78E-03 5.62E-03 1.78E-03 5.80E-03 2.29E-03 8.05E-03 2.29E-03 8.54E-03 2.29E-03 8.74E-03 0.01 0.04Ethylbenzene 100-41-4 3.98E-03 0.01 3.98E-03 0.01 5.13E-03 0.02 5.13E-03 0.02 5.13E-03 0.02 0.02 0.08Ethylene dibromide 106-93-4 5.08E-05 1.61E-04 5.08E-05 1.66E-04 6.55E-05 2.30E-04 6.55E-05 2.44E-04 6.55E-05 2.50E-04 2.98E-04 1.05E-03Ethylene dichloride 107-06-2 1.69E-03 5.36E-03 1.69E-03 5.52E-03 2.18E-03 7.67E-03 2.18E-03 8.13E-03 2.18E-03 8.33E-03 9.94E-03 0.04Formaldehyde 50-00-0 0.44 1.39 0.44 1.43 0.06 0.22 0.06 0.23 0.06 0.24 1.06 3.50Isomers of xylene 1330-20-7 1.57E-03 4.95E-03 1.57E-03 5.11E-03 2.02E-03 7.09E-03 2.02E-03 7.52E-03 2.02E-03 7.70E-03 9.19E-03 0.03Isophorone 78-59-1 0.02 0.08 0.02 0.08 0.03 0.11 0.03 0.12 0.03 0.12 0.14 0.51Isopropylbenzene 98-82-8 2.24E-04 7.10E-04 2.24E-04 7.31E-04 2.89E-04 1.02E-03 2.89E-04 1.08E-03 2.89E-04 1.10E-03 1.32E-03 4.64E-03Methyl bromide 74-83-9 6.77E-03 0.02 6.77E-03 0.02 8.74E-03 0.03 8.74E-03 0.03 8.74E-03 0.03 0.04 0.14Methyl chloride 74-87-3 0.02 0.07 0.02 0.07 0.03 0.10 0.03 0.11 0.03 0.11 0.13 0.46Methyl hydrazine 60-34-4 7.20E-03 0.02 7.20E-03 0.02 9.28E-03 0.03 9.28E-03 0.03 9.28E-03 0.04 0.04 0.15Methyl methacrylate 80-62-6 8.47E-04 2.68E-03 8.47E-04 2.76E-03 1.09E-03 3.83E-03 1.09E-03 4.07E-03 1.09E-03 4.16E-03 4.97E-03 0.02N-Hexane 110-54-3 2.84E-03 8.97E-03 2.84E-03 9.25E-03 3.66E-03 0.01 3.66E-03 0.01 3.66E-03 0.01 0.02 0.06Perchloroethylene 127-18-4 1.82E-03 5.76E-03 1.82E-03 5.93E-03 2.35E-03 8.24E-03 2.35E-03 8.74E-03 2.35E-03 8.95E-03 0.01 0.04Phenol 108-95-2 6.77E-04 2.14E-03 6.77E-04 2.21E-03 8.74E-04 3.07E-03 8.74E-04 3.25E-03 8.74E-04 3.33E-03 3.98E-03 0.01Propionaldehyde 123-38-6 0.02 0.05 0.02 0.05 0.02 0.07 0.02 0.08 0.02 0.08 0.09 0.33Pyrene 129-00-0 1.40E-05 4.42E-05 1.40E-05 4.55E-05 1.80E-05 6.33E-05 1.80E-05 6.71E-05 1.80E-05 6.87E-05 8.20E-05 2.89E-04Styrene 100-42-5 1.06E-03 3.35E-03 1.06E-03 3.45E-03 1.36E-03 4.79E-03 1.36E-03 5.08E-03 1.36E-03 5.21E-03 6.21E-03 0.02Tert-butyl methyl ether 1634-04-4 1.48E-03 4.69E-03 1.48E-03 4.83E-03 1.91E-03 6.71E-03 1.91E-03 7.12E-03 1.91E-03 7.29E-03 8.70E-03 0.03Toluene 108-88-3 0.01 0.03 0.01 0.03 0.01 0.05 0.01 0.05 0.01 0.05 0.06 0.21Vinyl acetate 108-05-4 3.22E-04 1.02E-03 3.22E-04 1.05E-03 4.15E-04 1.46E-03 4.15E-04 1.55E-03 4.15E-04 1.58E-03 1.89E-03 6.65E-03MetalsAntimony 7440-36-0 7.62E-04 2.41E-03 7.62E-04 2.48E-03 9.83E-04 3.45E-03 9.83E-04 3.66E-03 9.83E-04 3.75E-03 4.47E-03 0.02Arsenic 7440-38-2 0.02 0.05 0.02 0.06 0.02 0.08 0.02 0.08 0.02 0.09 0.10 0.36Beryllium 7440-41-7 8.89E-04 2.81E-03 8.89E-04 2.90E-03 1.15E-03 4.03E-03 1.15E-03 4.27E-03 1.15E-03 4.37E-03 5.22E-03 0.02Cadmium 7440-43-9 2.16E-03 6.83E-03 2.16E-03 7.04E-03 2.78E-03 9.78E-03 2.78E-03 0.01 2.78E-03 0.01 0.01 0.04Chromium 7440-47-3 0.01 0.03 0.01 0.04 0.01 0.05 0.01 0.05 0.01 0.05 0.06 0.23Chromium (VI) 18540-29-9 3.34E-03 0.01 3.34E-03 0.01 4.31E-03 0.02 4.31E-03 0.02 4.31E-03 0.02 0.02 0.07Cobalt 7440-48-4 4.23E-03 0.01 4.23E-03 0.01 5.46E-03 0.02 5.46E-03 0.02 5.46E-03 0.02 0.02 0.09

Pollutant CAS

Boiler 5 Boiler 6 Boiler 7 Boiler 8 Boiler 9 Total Project Emissions


Table 7 - Total HAP Emissions for ProjectAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan


Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)

Max Emissions

(lb/hr)

Annual Emissions

(tpy)


Annual Emissions

(tpy)

Pollutant CAS

Boiler 5 Boiler 6 Boiler 7 Boiler 8 Boiler 9 Total Project Emissions

Lead 7439-92-1 0.02 0.06 0.02 0.06 0.02 0.08 0.02 0.09 0.02 0.09 0.10 0.37Manganese 7439-96-5 0.02 0.07 0.02 0.07 0.03 0.09 0.03 0.10 0.03 0.10 0.12 0.43Mercury 7439-97-6 1.19E-03 3.78E-03 1.19E-03 3.89E-03 1.21E-03 4.26E-03 1.21E-03 4.51E-03 1.21E-03 4.62E-03 6.02E-03 0.02Nickel 7440-02-0 0.01 0.04 0.01 0.04 0.02 0.05 0.02 0.06 0.02 0.06 0.07 0.25Selenium 7782-49-2 0.06 0.17 0.06 0.18 0.07 0.25 0.07 0.26 0.07 0.27 0.32 1.14PAHs5-Methyl Chrysene 3697-24-3 9.31E-07 2.95E-06 9.31E-07 3.04E-06 1.20E-06 4.22E-06 1.20E-06 4.47E-06 1.20E-06 4.58E-06 5.47E-06 1.93E-05Acenaphthene 83-32-9 2.16E-05 6.83E-05 2.16E-05 7.04E-05 2.78E-05 9.78E-05 2.78E-05 1.04E-04 2.78E-05 1.06E-04 1.27E-04 4.46E-04Acenaphthylene 208-96-8 1.06E-05 3.35E-05 1.06E-05 3.45E-05 1.36E-05 4.79E-05 1.36E-05 5.08E-05 1.36E-05 5.21E-05 6.21E-05 2.19E-04Anthracene 120-12-7 8.89E-06 2.81E-05 8.89E-06 2.90E-05 1.15E-05 4.03E-05 1.15E-05 4.27E-05 1.15E-05 4.37E-05 5.22E-05 1.84E-04Benzo (a) anthracene 56-55-3 6.78E-06 2.14E-05 6.78E-06 2.21E-05 4.37E-06 1.53E-05 4.37E-06 1.63E-05 4.37E-06 1.67E-05 2.67E-05 9.18E-05Benzo (a) pyrene 50-32-8 9.63E-06 3.04E-05 9.63E-06 3.14E-05 2.07E-06 7.29E-06 2.07E-06 7.73E-06 2.07E-06 7.91E-06 2.55E-05 8.47E-05Benzo (g,h,i) perylene 191-24-2 1.14E-06 3.61E-06 1.14E-06 3.73E-06 1.47E-06 5.18E-06 1.47E-06 5.49E-06 1.47E-06 5.62E-06 6.71E-06 2.36E-05Benzofluoranthenes 56832-73-6 4.66E-06 1.47E-05 4.66E-06 1.52E-05 6.01E-06 2.11E-05 6.01E-06 2.24E-05 6.01E-06 2.29E-05 2.73E-05 9.63E-05Biphenyl 92-52-4 7.20E-05 2.28E-04 7.20E-05 2.35E-04 9.28E-05 3.26E-04 9.28E-05 3.46E-04 9.28E-05 3.54E-04 4.22E-04 1.49E-03Chrysene 218-01-9 9.99E-06 3.16E-05 9.99E-06 3.25E-05 5.46E-06 1.92E-05 5.46E-06 2.03E-05 5.46E-06 2.08E-05 3.64E-05 1.24E-04Fluoranthene 206-44-0 3.01E-05 9.51E-05 3.01E-05 9.80E-05 3.88E-05 1.36E-04 3.88E-05 1.44E-04 3.88E-05 1.48E-04 1.76E-04 6.21E-04Fluorene 86-73-7 3.85E-05 1.22E-04 3.85E-05 1.26E-04 4.97E-05 1.74E-04 4.97E-05 1.85E-04 4.97E-05 1.89E-04 2.26E-04 7.96E-04Indeno(1,2,3-cd)pyrene 193-39-5 2.58E-06 8.17E-06 2.58E-06 8.42E-06 3.33E-06 1.17E-05 3.33E-06 1.24E-05 3.33E-06 1.27E-05 1.52E-05 5.34E-05Naphthalene 91-20-3 2.39E-03 7.56E-03 2.39E-03 7.80E-03 7.10E-04 2.49E-03 7.10E-04 2.64E-03 7.10E-04 2.71E-03 6.91E-03 0.02Phenanthrene 85-01-8 1.14E-04 3.61E-04 1.14E-04 3.73E-04 1.47E-04 5.18E-04 1.47E-04 5.49E-04 1.47E-04 5.62E-04 6.71E-04 2.36E-03Polycyclic organic matter (POM) 0.02 0.07 0.02 0.08 3.34E-03 0.01 3.34E-03 0.01 3.34E-03 0.01 0.06 0.19Dioxins/Furans2,3,7,8-Tetrachlorodibenzofuran 51207-31-9 2.16E-09 6.83E-09 2.16E-09 7.04E-09 2.78E-09 9.78E-09 2.78E-09 1.04E-08 2.78E-09 1.06E-08 1.27E-08 4.46E-082,3,7,8-Tetrachlorodibenzo-p-dioxin 1746-01-6 6.05E-10 1.91E-09 6.05E-10 1.97E-09 7.81E-10 2.74E-09 7.81E-10 2.91E-09 7.81E-10 2.98E-09 3.55E-09 1.25E-08

Heptachlorodibenzofurans, total 3.25E-09 1.03E-08 3.25E-09 1.06E-08 4.19E-09 1.47E-08 4.19E-09 1.56E-08 4.19E-09 1.60E-08 1.91E-08 6.72E-08Heptachlorodibenzo-p-dioxins, total 37871-00-4 3.53E-09 1.12E-08 3.53E-09 1.15E-08 4.55E-09 1.60E-08 4.55E-09 1.70E-08 4.55E-09 1.74E-08 2.07E-08 7.30E-08Hexachlorodibenzofurans, total 8.13E-09 2.57E-08 8.13E-09 2.65E-08 1.05E-08 3.68E-08 1.05E-08 3.90E-08 1.05E-08 4.00E-08 4.77E-08 1.68E-07Hexachlorodibenzo-p-dioxins, total 34465-46-8 1.22E-09 3.84E-09 1.22E-09 3.96E-09 1.57E-09 5.50E-09 1.57E-09 5.84E-09 1.57E-09 5.98E-09 7.13E-09 2.51E-08Octachlorodibenzofurans, total 39001-02-0 2.81E-09 8.88E-09 2.81E-09 9.15E-09 3.62E-09 1.27E-08 3.62E-09 1.35E-08 3.62E-09 1.38E-08 1.65E-08 5.80E-08Octachlorodibenzo-p-dioxins, total 3268-87-9 1.76E-08 5.57E-08 1.76E-08 5.74E-08 2.27E-08 7.98E-08 2.27E-08 8.46E-08 2.27E-08 8.66E-08 1.03E-07 3.64E-07

Pentachlorodibenzofurans, total 30402-15-4 1.49E-08 4.73E-08 1.49E-08 4.87E-08 1.93E-08 6.77E-08 1.93E-08 7.18E-08 1.93E-08 7.35E-08 8.77E-08 3.09E-07Pentachlorodibenzo-p-dioxins, total 1.89E-09 5.98E-09 1.89E-09 6.17E-09 2.44E-09 8.57E-09 2.44E-09 9.09E-09 2.44E-09 9.31E-09 1.11E-08 3.91E-08Polychlorinated dibenzofurans, total 136677-10-6 4.62E-08 1.46E-07 4.62E-08 1.50E-07 5.95E-08 2.09E-07 5.95E-08 2.22E-07 5.95E-08 2.27E-07 2.71E-07 9.54E-07Polychlorinated dibenzo-p-dioxins and furans, total 7.45E-08 2.36E-07 7.45E-08 2.43E-07 9.61E-08 3.37E-07 9.61E-08 3.58E-07 9.61E-08 3.66E-07 4.37E-07 1.54E-06Polychlorinated dibenzo-p-dioxins, total 2.82E-08 8.92E-08 2.82E-08 9.19E-08 3.64E-08 1.28E-07 3.64E-08 1.35E-07 3.64E-08 1.39E-07 1.65E-07 5.83E-07Tetrachlorodibenzofurans, total 1.71E-08 5.41E-08 1.71E-08 5.57E-08 2.21E-08 7.75E-08 2.21E-08 8.22E-08 2.21E-08 8.41E-08 1.00E-07 3.54E-07Tetrachlorodibenzo-p-dioxins, total 3.93E-09 1.24E-08 3.93E-09 1.28E-08 5.07E-09 1.78E-08 5.07E-09 1.89E-08 5.07E-09 1.93E-08 2.31E-08 8.12E-08

TOTAL 87.89


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Table 8 – Model Input Parameters - Point SourcesAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Easting NorthingBOILER 5 Past Actuals B5OLD 469722 5158443 606.5 400 9 313 275,400 72.15024 -256.6 -690.4 -84.6 -12.95BOILER 6 Past Actuals B6OLD 469722 5158447 606.5 400 9 310 272,000 71.2595 -237.4 -678.2 -99.5 -14.02BOILER 7 Past Actuals B7OLD 469725 5158504 606.5 400 9.5 345 353,100 83.02509 -319.6 -390.2 -9.6 -15.27BOILER 8 Past Actuals B8OLD 469721 5158506 606.5 400 9.5 335 352,100 82.78996 -342.9 -421.5 -8.9 -13.81BOILER 9 Past Actuals B9OLD 469725 5158508 606.5 400 9.5 341 342,000 80.41513 -337.2 -413.5 -7.4 -16.27Boilers 5 & 6 995 MMBtu/hr B56N_995 469725 5158445 606.5 400 11 180 565,000 99.0882 497.6 159.2 398 47.8Boilers 5 & 6 680 MMBtu/hr B56N_680 469725 5158445 606.5 400 11 180 525,000 92.07311 340 108.8 272 32.6EUBOILER7 B7NEW 469722 5158447 606.5 400 9 179 310,000 81.21487 252.5 80.8 202 24.2EUBOILER8 B8NEW 469721 5158506 606.5 400 9.5 335 383,250 90.11432 252.5 454.5 202 24.2EUBOILER9 B9NEW 469725 5158508 606.5 400 9.5 335 383,250 90.11432 252.5 454.5 202 24.2DSI Silo Vent1 DSIVENT 469643 5158590 613.3 60 1.595 Ambient - 0.003281 - - - 0.036New PAC Silo Vent2 NEWPAC 469722 5158495 610.0 50 1.595 Ambient - 0.003281 - - - 0.0086Pebble Lime Silo Vent1 PEBVENT 469720 5158351 606.5 60 1.595 Ambient - 0.003281 - - - 0.0343

1. PM Emissions for these sources occur only during unloading of materials from haul trucks. It is assumed trucks will be unloaded no more than 12 hours per day.2. PM Emissions for these sources occur only during unloading of materials from haul trucks. It is assumed trucks will be unloaded no more than 4 hours per day.3. As these units have a horizontal release, the true exhaust flow rate is not used in the model. Instead, a velocity of 0.001 m/s (0.003281 ft/s) is used.

Exhaust Temperature

(deg F)

SO2

Emission Rate

(lbs/hr)

CO Emission

Rate (lbs/hr)

PM10/PM2.5

Emission Rate

(lbs/hr)Source Model Name

Exit Velocity3

(fps)

Stack Height (feet)

Stack Diameter

(feet)

Exhaust Flow Rate3

(acfm)

NOx

Emission Rate

(lbs/hr)

NAD 83 UTM Coordinates

Base Elevation

(feet)

Z:\2012\120697\WORK\Rept\PTI Application\WP_We_Emissions_2013_0301.xlsx 3/2/2013

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Easting NorthingHaul Road Segment A Volume EQ0XU0BD 468872.1 5158625.6 612.53 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BE 468883.4 5158631.9 612.40 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BF 468894.7 5158638.2 612.27 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BG 468906 5158644.6 612.14 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BH 468917.3 5158650.9 612.04 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BI 468928.6 5158657.2 611.94 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BJ 468941 5158660 611.75 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BK 468953.9 5158661.2 611.58 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BL 468966.8 5158662.4 611.55 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BM 468979.7 5158663.6 611.65 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BN 468992.6 5158664.7 612.04 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BO 469005.5 5158665.9 612.83 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BP 469018.4 5158667.1 614.01 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BQ 469031.3 5158667 615.35 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BR 469044.1 5158665.6 617.06 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BS 469057 5158664.2 618.83 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BT 469069.9 5158662.8 619.85 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BU 469082.8 5158661.4 620.37 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BV 469095.6 5158660 620.44 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BW 469108.5 5158658.6 621.49 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BX 469121.4 5158657.2 621.92 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BY 469134.3 5158655.8 621.95 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0BZ 469147.1 5158654.4 621.46 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C0 469160 5158653 620.08 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C1 469172.9 5158651.7 619.46 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C2 469185.8 5158650.9 619.00 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C3 469198.7 5158650.1 618.47 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C4 469211.7 5158649.2 618.01 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C5 469224.6 5158648.4 617.59 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C6 469237.5 5158647.6 617.16 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C7 469250.4 5158646.7 616.67 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C8 469263.4 5158645.9 616.27 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0C9 469276.3 5158645.1 615.91 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CA 469289.2 5158644.2 615.62 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CB 469302.1 5158643.4 615.39 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CC 469315.1 5158642.6 615.22 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CD 469327.9 5158640.9 615.06 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CE 469340.7 5158639 614.96 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CF 469353.5 5158637.1 614.80 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CG 469366.3 5158635.3 614.67 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CH 469379.1 5158633.4 614.53 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CI 469391.9 5158631.5 614.47 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CJ 469404.8 5158629.6 614.40 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CK 469417.6 5158627.7 614.34 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CL 469430.4 5158625.8 614.27 9.77 21.25 9.09 1.45E-05 5.90E-05

Table 9 – Model Input Parameters - Volume SourcesAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

PM2.5

Emission Rate (g/s)Source Type

Initial Vertical

Dimension (feet)

PM10

Emission Rate (g/s)Source Model Name


Base Elevation

(feet)

Release Height (feet)

Initial Lateral

Dimension (feet)


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Easting Northing

Table 9 – Model Input Parameters - Volume SourcesAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

PM2.5

Emission Rate (g/s)Source Type

Initial Vertical

Dimension (feet)

PM10

Emission Rate (g/s)Source Model Name


Base Elevation

(feet)

Release Height (feet)

Initial Lateral

Dimension (feet)

Haul Road Segment A Volume EQ0XU0CM 469443.2 5158623.9 614.27 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CN 469456 5158622 614.24 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CO 469468.4 5158622.9 614.30 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CP 469479.9 5158628.8 614.47 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CQ 469491.4 5158634.8 614.63 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CR 469502.9 5158640.7 614.80 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CS 469514.3 5158646.7 614.96 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CT 469525.8 5158652.7 615.12 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CU 469538.6 5158652.4 615.09 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CV 469551.6 5158651.6 615.09 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CW 469564.3 5158650.2 615.09 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CX 469576.2 5158644.9 614.93 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CY 469588 5158639.6 614.80 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0CZ 469599.8 5158634.3 614.67 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0D0 469611.6 5158629 614.53 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0D1 469623.4 5158623.7 614.37 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0D2 469635.3 5158618.4 614.21 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment A Volume EQ0XU0D3 469647.1 5158613.1 614.01 9.77 21.25 9.09 1.45E-05 5.90E-05Haul Road Segment B Volume EQ0XU0D5 469655.4 5158608.5 613.85 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0D6 469665.7 5158600.7 613.62 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0D7 469676.1 5158592.9 613.39 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0D8 469685.1 5158583.7 613.09 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0D9 469693 5158573.5 612.80 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DA 469700.8 5158563.2 612.43 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DB 469708 5158552.4 612.01 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DC 469714.7 5158541.3 611.55 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DD 469721.2 5158530.2 611.09 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DE 469727.7 5158518.9 610.66 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DF 469733.6 5158507.5 610.24 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment B Volume EQ0XU0DG 469735.1 5158494.7 609.91 9.77 21.25 9.09 7.64E-06 3.11E-05Haul Road Segment C Volume EQ0XU0DI 469737.8 5158481.7 609.58 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DJ 469738.3 5158468.8 609.32 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DK 469738.8 5158455.8 608.99 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DL 469739.3 5158442.9 608.66 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DM 469739.8 5158429.9 608.33 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DN 469743.5 5158418 608.01 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DO 469750.3 5158406.9 607.71 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DP 469750.9 5158394.2 607.38 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DQ 469750.6 5158381.3 607.05 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DR 469748.6 5158368.8 606.69 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DS 469741.4 5158358.1 606.46 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DT 469739.9 5158345.7 606.14 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DU 469740.7 5158332.8 605.77 9.77 21.25 9.09 6.17E-06 2.52E-05Haul Road Segment C Volume EQ0XU0DV 469751.8 5158339.1 605.87 9.77 21.25 9.09 6.17E-06 2.52E-05


of 1

Table 10 – SIL Model Results SummaryAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

2007 2008 2009 2010 2011 MaximumNO2 12.61 7.6 1-hr Yes 1ST-HIGHEST MAX DAILY 1-HRSO2 2.42 7.9 1-hr No 1ST-HIGHEST MAX DAILY 1-HRCO 187.70 210.26 203.22 209.78 212.01 212.01 2,000 1-hr No 1-hrCO 35.53 53.01 53.45 38.16 39.86 53.45 500 8-hr No 8-hrPM25 1.11 1.2 24-hr No 1ST-HIGHEST 24-HRPM10 1.73 1.74 1.70 1.60 1.32 1.73 5 24-hr No 24-hrNO2 12.18 7.6 1-hr Yes 1ST-HIGHEST MAX DAILY 1-HRSO2 2.32 7.9 1-hr No 1ST-HIGHEST MAX DAILY 1-HRCO 160.30 177.41 171.47 177.60 176.25 177.60 2,000 1-hr No 1-hrCO 30.63 44.32 45.58 32.85 34.33 45.58 500 8-hr No 8-hrPM25 1.11 1.2 24-hr No 1ST-HIGHEST 24-HRPM10 1.73 1.74 1.70 1.60 1.20 1.73 5 24-hr No 24-hr

All NOx emissions were assumed to be NO2 for SIL analysis run without PVMRM (Tier 1 method).Impacts for short-term NO2 and SO2 are the 1st-highest maximum daily 1-hour impacts, averaged over 5 years. PM2.5 short-term impacts are the 1st-highest 24-hour impacts, averaged over 5 years.Impacts for PM10 and CO are the high, 1st high maximum over 5 years.

CHANG680

All Boilers Operating, Units 5 & 6 at 995

MMBtu/hr

All Boilers Operating, Units 5 & 6 at 680

MMBtu/hr

SIL Averaging

Period

12.182.32

1.11

1.11

Exceeds SIL Averaging Period

12.612.42

Operating Scenario Model Group PollutantMaximum Predicted Impacts SIL

(µg/m3)

CHANG995


of 1

Table 11 – CO Start-up/Shutdown SIL Model Results SummaryAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

2007 2008 2009 2010 2011 Maximum

CO 1,103 1,493 1,093 1,261 1,392 1,493 2,000 1-hr No 1-hr

CO 252 310 307 253 288 310 500 8-hr No 8-hr

CO 1,005 1,328 995 1,097 1,253 1,328 2,000 1-hr No 1-hr

CO 226 277 269 227 259 277 500 8-hr No 8-hr

Maximum Predicted Impacts presented above are for both the 995 MMBtu/hr and the 680 MMBtu/hr scenario. The modeled lb/hr inputs are listed below.

Model Input for Start-up/Shutdown

Model Group

Baseload Emissions

Rate (lbs/hr)

Start-up/ Shutdown Emission

Rate (lbs/hr)

Baseload Exhaust

Flow Rate (acfm)

Start-up/ Shutdown

Exhaust Flow Rate

(acfm)*B56N_995 398 1194 565,000 282,500*B56N_680 272 816 525,000 262,500B7NEW 202 606 310,000 155,000B8NEW 202 606 383,250 191,625B9NEW 202 606 383,250 191,625

*Note that for Boilers 5 and 6 (995 MMBtu/hr), the estimated start-up/shutdown emission rate is 597 lb/hr for each boiler or a combined 1194 lb/hr. Boilers 5 and 6 (680 MMBtu/hr), the estimated start-up/shutdown emission rate is 408 lb/hr for each boiler or a combined 816 lb/hr.

All boilers starting up simultaneously,

3x baseload Emission RateSIL680_3

Exceeds SIL

Averaging Period

All boilers starting up simultaneously,

3x baseload Emission RateSIL995_3

Operating Scenario Model Group Pollutant

Maximum Predicted Impacts(µg/m3) SIL

(µg/m3)

SIL Averaging

Period


of 1

Air Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

2007 2008 2009 2010 2011

All Boilers Operating, Units 5 & 6 at 995 MMBtu/hr (Including

Emergency Equipment and Off-Site Sources)

NAAQS995 NO2 14.4 78.5 188 1-hr No 8TH-HIGHEST MAX DAILY 1-HR

All Boilers Operating, Units 5 & 6 at 680 MMBtu/hr (Including

Emergency Equipment and Off-Site Sources)

NAAQS680 NO2 14.4 71.9 188 1-hr No 8TH-HIGHEST MAX DAILY 1-HR

Notes: All NOx emissions were assumed to be NO2 for the NAAQS analysis run without PVMRM (Tier 1 method). The regional NO2 background concentration was provided by MDEQ and represents the Forest County (northern Wisconsin) monitor.

57.5

PAI(Maximum + Background)

(µg/m3)

NAAQS(µg/m3)

NAAQS Averaging

Period

Exceeds NAAQS

Table 12 – NAAQS Model Results

Averaging Period

64.1

Operating Scenario Model Group PollutantMaximum Predicted Impacts (µg/m3)

Background(µg/m3)


of 1

Table 13 - Unitized TAC Model ResultsAir Use Permit to Install AQCS Retrofit PIPP

Boilers_ 5_6_995 Boilers_ 5_6_680 Boiler 7 Boiler 8 Boiler 9

Annual 2.12E-03 2.23E-03 3.06E-03 1.94E-03 1.94E-031-hr 2.92E-01 2.95E-01 3.76E-01 2.59E-01 2.59E-013-hr 9.72E-02 9.84E-02 1.25E-01 8.64E-02 8.64E-028-hr 5.05E-02 5.30E-02 7.20E-02 4.32E-02 4.32E-02

24-hr 2.59E-02 2.70E-02 3.52E-02 2.35E-02 2.34E-02

Model PAI (ug/m3)/(lb/hr)Averaging Period



Table 14 - PAH Relative PotencyAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette,

Emissions(lb/hr)

Max relative B(a)P Emissions

based on Potency(lb/hr)

Emissions(lb/hr)

Max relative B(a)P

Emissions based on Potency(lb/hr)

Emissions(lb/hr)



Emissions(lb/hr)



Emissions

(lb/hr)



benzo(a)pyrene 50-32-8 1 9.63E-06 9.6E-06 9.63E-06 9.6E-06 2.07E-06 2.1E-06 2.07E-06 2.1E-06 2.07E-06 2.1E-06benzo(a)anthracene 56-55-3 0.1 6.78E-06 6.8E-07 6.78E-06 6.8E-07 4.37E-06 4.4E-07 4.37E-06 4.4E-07 4.37E-06 4.4E-07benzo(b)fluoranthene1 205-99-2 0.1 4.66E-06 4.7E-07 4.66E-06 4.7E-07 6.01E-06 6.0E-07 6.01E-06 6.0E-07 6.01E-06 6.0E-07benzo(k)fluoranthene 207-08-9 0.01 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00benzo(b)fluoranthene 205-99-2 0.1 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00chrysene 218-01-9 0.001 9.99E-06 1.0E-08 9.99E-06 1.0E-08 5.46E-06 5.5E-09 5.46E-06 5.5E-09 5.46E-06 5.5E-09dibenzo(a,h)anthracene 53-70-3 1 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00indeno(1,2,3-cd)pyrene 193-39-5 0.1 2.58E-06 2.6E-07 2.58E-06 2.6E-07 3.33E-06 3.3E-07 3.33E-06 3.3E-07 3.33E-06 3.3E-077,12-Dimethylbenz(a)anthracene 57-97-6 0.1 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+00 NA 0.0E+005-methyl chrysene 3697-24-3 0.1 9.31E-07 9.3E-08 9.31E-07 9.3E-08 1.20E-06 1.2E-07 1.20E-06 1.2E-07 1.20E-06 1.2E-07SUM 7-carcinogenic PAHs 3.46E-05 1.11E-05 3.46E-05 1.11E-05 2.24E-05 3.57E-06 2.24E-05 3.57E-06 2.24E-05 3.57E-06

Boiler 7 Boiler 8 Boiler 9

The 7 carcinogenic PAHs include benzo(a)pyrene, benzo(a)anthracene, benzo(b)fluoranthene, benzo(k)fluoranthene, chrysene, dibenzo(a,h)anthracene, and indeno(1,2,3-cd)pyrene. 5-Methyl chyrsene was included in the carcinogenic PAC table, since it is listed as a possible carcinogen, and has been shown to be mutagenic in vitro. The relative potency of 5-methyl chrysene compared to B(a)P is assumed to be 0.1, as recommended by the Scientific Advisory Panel on Carcinogenic PAHs (July 20, 1995) which recommended use of equivalency factors of 0.1 for compounds that are expected to be carcinogenic, but not quantified.

Relative Potency obtained from EPA Provisional Guidance for Quantitative Risk Assesment of Polycyclic Aromatic Hydrocarbons (EPA/600/R-93/089, July 1993)

Boiler 5 Boiler 6

Pollutant CAS

Estimated Order of Potential Potency

Relative to B(a)P

1 Emission calculations for benzofluoranthenes are based on emission factors for benzo(b,k)fluoranthene, which includes the 2 isomers (b & k) of benzofluoranthene. Benzo(b,k)fluoranthene is assumed to be all benzo(b)fluoranthene since it has the largest estimated order of potential potency of the b and k isomers.

Carcinogenic PAHs


Table 15 - Dioxin Furan Relative PotencyAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Emissions(lb/hr)

Max relative TCDD

Emissions based on

TEF(lb/hr)

Emissions

(lb/hr)

Max relative TCDD

Emissions based on

TEF(lb/hr)

Emissions(lb/hr)

Max relative TCDD

Emissions based on

TEF(lb/hr)

Emissions(lb/hr)

Max relative TCDD

Emissions based on

TEF(lb/hr)

Emissions(lb/hr)

Max relative TCDD

Emissions based on

TEF(lb/hr)

2,3,7,8-TCDD 1746-01-6 1 6.05E-10 6.1E-10 6.05E-10 6.1E-10 7.81E-10 7.8E-10 7.81E-10 7.8E-10 7.81E-10 7.8E-10Total PeCDD 1 1.89E-09 1.9E-09 1.89E-09 1.9E-09 2.44E-09 2.4E-09 2.44E-09 2.4E-09 2.44E-09 2.4E-09Total HxCDD 34465-46-8 0.1 1.22E-09 1.2E-10 1.22E-09 1.2E-10 1.57E-09 1.6E-10 1.57E-09 1.6E-10 1.57E-09 1.6E-10Total HpCDD 0.01 3.53E-09 3.5E-11 3.53E-09 3.5E-11 4.55E-09 4.6E-11 4.55E-09 4.6E-11 4.55E-09 4.6E-11Total OCDD 0.0003 1.76E-08 5.3E-12 1.76E-08 5.3E-12 2.27E-08 6.8E-12 2.27E-08 6.8E-12 2.27E-08 6.8E-122,3,7,8-TCDF 51207-31-8 0.1 2.16E-09 2.2E-10 2.16E-09 2.2E-10 2.78E-09 2.8E-10 2.78E-09 2.8E-10 2.78E-09 2.8E-10Total PeCDF (assumed to be 2,3,4,7,8-PeCDF) 0.3 1.49E-08 4.5E-09 1.49E-08 4.5E-09 1.93E-08 5.8E-09 1.93E-08 5.8E-09 1.93E-08 5.8E-09Total HxCDF 0.1 8.13E-09 8.1E-10 8.13E-09 8.1E-10 1.05E-08 1.0E-09 1.05E-08 1.0E-09 1.05E-08 1.0E-09Total HpCDF 0.01 3.25E-09 3.3E-11 3.25E-09 3.3E-11 4.19E-09 4.2E-11 4.19E-09 4.2E-11 4.19E-09 4.2E-11Total OCDF 0.0003 2.81E-09 8.4E-13 2.81E-09 8.4E-13 3.62E-09 1.1E-12 3.62E-09 1.1E-12 3.62E-09 1.1E-12Total PCDD/PCDF 7.45E-08 7.45E-08 9.61E-08 9.61E-08 9.61E-08

1.31E-07 8.21E-09 1.31E-07 8.21E-09 1.68E-07 1.06E-08 1.68E-07 1.06E-08 1.68E-07 1.06E-08Calculations

PCDD = Polychlorinated dibenzo(p)dioxinsPCDF = Polychlorinated dibenzofuransTEF = Toxic Equivalency Factor, which were obtained from The 2005 World Health

Organization Reevaluation of Human and Mammalian Toxic Equivalency Factors for

Dioxins and Dioxin-Like Compounds Table 1.WHO = World Health OrganizationThe following congeners have more than one TEF - HxCDD, PeCDF, HxCDF and HpCDF.Worst case TEF was used for congeners with multiple TEFs.Max TCDD Emissions based on TEF (lb/hr) = Max Congener Emission Rate (lb/hr) x TEFTEF for Total PCDD/PCDF calculated based on weighted average of emission rate and TEF.

Boiler 8 Boiler 9

PCDD & PCDF Emissions based on relative potency (lb/hr) = Estimated Mass Emission Rate (lb/hr) x Potential Potency Relative to 2,3,7,8-TCDD & TCDF (respectively).

PCDD and PCDFs

Boiler 5 Boiler 6 Boiler 7

Pollutant CASWHO 2005 TEF


of 2

Table 16 - Maximum Potential Ambient ImpactsAir Use Permit to Install AQCS Retrofit PIPP

Emissions (lb/hr)

Model Results(µg/m3)/(lb/hr)

Emissions (lb/hr)


Emissions (lb/hr)


Emissions (lb/hr)


Emissions (lb/hr)


Toxic Air ContaminantsAmmonia 7664-41-7 11.49 2.59E-02 11.49 2.70E-02 0.81 3.52E-02 0.81 2.35E-02 0.81 2.34E-02 0.38 100 24-hr ITSL 0.4% PASS

3.98 2.12E-03 2.72 2.23E-03 2.02 3.06E-03 2.02 1.94E-03 2.02 1.94E-03 0.02 20 annual ITSL 0.1% PASS3.98 2.92E-01 2.72 2.95E-01 2.02 3.76E-01 2.02 2.59E-01 2.02 2.59E-01 2.97 2100 1-hr 2nd ITSL 0.1% PASS2.54 2.12E-03 2.21 2.23E-03 1.64 3.06E-03 3.28 1.94E-03 3.28 1.94E-03 0.02 14 annual ITSL 0.2% PASS2.54 2.92E-01 2.21 2.95E-01 1.64 3.76E-01 3.28 2.59E-01 3.28 2.59E-01 3.05 240 1-hr 2nd ITSL 1.3% PASS2.62 2.12E-03 2.27 2.23E-03 1.69 3.06E-03 3.37 1.94E-03 3.37 1.94E-03 0.02 1 annual ITSL 2.4% PASS2.62 2.92E-01 2.27 2.95E-01 1.69 3.76E-01 3.37 2.59E-01 3.37 2.59E-01 3.14 120 1-hr 2nd ITSL 2.6% PASS

Organics1,1,1-Trichloroethane 71-55-6 1.69E-03 2.59E-02 1.47E-03 2.70E-02 1.09E-03 3.52E-02 1.09E-03 2.35E-02 1.09E-03 2.34E-02 1.33E-04 6000 24-hr ITSL 0.0% PASS

2.37E-05 5.05E-02 2.06E-05 5.30E-02 1.53E-05 7.20E-02 1.53E-05 4.32E-02 1.53E-05 4.32E-02 3.62E-06 2 8-hr ITSL 0.0% PASS2.37E-05 2.12E-03 2.06E-05 2.23E-03 1.53E-05 3.06E-03 1.53E-05 1.94E-03 1.53E-05 1.94E-03 1.56E-07 0.009 annual IRSL 0.0% PASS

2-Chloroacetophenone 532-27-4 5.93E-04 2.59E-02 5.15E-04 2.70E-02 3.82E-04 3.52E-02 3.82E-04 2.35E-02 3.82E-04 2.34E-02 4.67E-05 0.03 24-hr ITSL 0.2% PASS0.05 2.59E-02 0.04 2.70E-02 0.03 3.52E-02 0.03 2.35E-02 0.03 2.34E-02 3.80E-03 9 24-hr ITSL 0.0% PASS0.05 2.12E-03 0.04 2.23E-03 0.03 3.06E-03 0.03 1.94E-03 0.03 1.94E-03 3.18E-04 0.5 annual IRSL 0.1% PASS

Acetophenone 98-86-2 1.27E-03 5.05E-02 1.10E-03 5.30E-02 8.19E-04 7.20E-02 8.19E-04 4.32E-02 8.19E-04 4.32E-02 1.94E-04 490 8-hr ITSL 0.0% PASS0.02 2.12E-03 0.02 2.23E-03 0.02 3.06E-03 0.02 1.94E-03 0.02 1.94E-03 1.62E-04 0.02 annual ITSL 0.8% PASS0.02 2.92E-01 0.02 2.95E-01 0.02 3.76E-01 0.02 2.59E-01 0.02 2.59E-01 0.02 5 1-hr 2nd ITSL 0.4% PASS0.11 2.12E-03 0.10 2.23E-03 0.07 3.06E-03 0.07 1.94E-03 0.07 1.94E-03 7.26E-04 30 annual ITSL 0.0% PASS0.11 2.59E-02 0.10 2.70E-02 0.07 3.52E-02 0.07 2.35E-02 0.07 2.34E-02 8.67E-03 30 24-hr 2nd ITSL 0.0% PASS0.11 2.12E-03 0.10 2.23E-03 0.07 3.06E-03 0.07 1.94E-03 0.07 1.94E-03 7.26E-04 0.1 annual IRSL 0.7% PASS

Benzyl chloride 100-44-7 0.06 2.12E-03 0.05 2.23E-03 0.04 3.06E-03 0.04 1.94E-03 0.04 1.94E-03 3.91E-04 0.02 annual IRSL 2.0% PASSBromoform 75-25-2 3.30E-03 2.12E-03 2.87E-03 2.23E-03 2.13E-03 3.06E-03 2.13E-03 1.94E-03 2.13E-03 1.94E-03 2.18E-05 0.9 annual IRSL 0.0% PASSCarbon sulfide 75-15-0 0.01 2.59E-02 9.56E-03 2.70E-02 7.10E-03 3.52E-02 7.10E-03 2.35E-02 7.10E-03 2.34E-02 8.67E-04 700 24-hr ITSL 0.0% PASSChlorobenzene 108-90-7 1.86E-03 2.59E-02 1.62E-03 2.70E-02 1.20E-03 3.52E-02 1.20E-03 2.35E-02 1.20E-03 2.34E-02 1.47E-04 70 24-hr ITSL 0.0% PASSChloroform 67-66-3 5.00E-03 2.12E-03 4.34E-03 2.23E-03 3.22E-03 3.06E-03 3.22E-03 1.94E-03 3.22E-03 1.94E-03 3.29E-05 0.4 annual IRSL 0.0% PASSCyanide 57-12-5 0.21 2.92E-01 0.18 2.95E-01 0.14 3.76E-01 0.14 2.59E-01 0.14 2.59E-01 0.18 50 1-hr ITSL 0.4% PASS

0.02 2.12E-03 0.02 2.23E-03 0.02 3.06E-03 0.02 1.94E-03 0.02 1.94E-03 1.62E-04 2000 annual ITSL 0.0% PASS0.02 2.92E-01 0.02 2.95E-01 0.02 3.76E-01 0.02 2.59E-01 0.02 2.59E-01 0.02 14000 1-hr 2nd ITSL 0.0% PASS0.02 2.12E-03 0.02 2.23E-03 0.02 3.06E-03 0.02 1.94E-03 0.02 1.94E-03 1.62E-04 60 annual IRSL 0.0% PASS

Dimethyl sulfate 77-78-1 4.06E-03 5.05E-02 3.53E-03 5.30E-02 2.62E-03 7.20E-02 2.62E-03 4.32E-02 2.62E-03 4.32E-02 6.20E-04 0.5 8-hr ITSL 0.1% PASSDioctyl phthalate 117-81-7 6.18E-03 2.12E-03 5.37E-03 2.23E-03 3.99E-03 3.06E-03 3.99E-03 1.94E-03 3.99E-03 1.94E-03 4.08E-05 0.2 annual IRSL 0.0% PASSEthyl chloride 75-00-3 3.56E-03 2.59E-02 3.09E-03 2.70E-02 2.29E-03 3.52E-02 2.29E-03 2.35E-02 2.29E-03 2.34E-02 2.80E-04 10000 24-hr ITSL 0.0% PASS

7.96E-03 2.59E-02 6.91E-03 2.70E-02 5.13E-03 3.52E-02 5.13E-03 2.35E-02 5.13E-03 2.34E-02 6.27E-04 1000 24-hr ITSL 0.0% PASS7.96E-03 2.12E-03 6.91E-03 2.23E-03 5.13E-03 3.06E-03 5.13E-03 1.94E-03 5.13E-03 1.94E-03 5.25E-05 3 annual IRSL 0.0% PASS1.02E-04 2.59E-02 8.82E-05 2.70E-02 6.55E-05 3.52E-02 6.55E-05 2.35E-02 6.55E-05 2.34E-02 8.01E-06 9 24-hr ITSL 0.0% PASS1.02E-04 2.12E-03 8.82E-05 2.23E-03 6.55E-05 3.06E-03 6.55E-05 1.94E-03 6.55E-05 1.94E-03 6.70E-07 0.002 annual IRSL 0.0% PASS

Ethylene dichloride 107-06-2 3.39E-03 2.12E-03 2.94E-03 2.23E-03 2.18E-03 3.06E-03 2.18E-03 1.94E-03 2.18E-03 1.94E-03 2.23E-05 0.04 annual IRSL 0.1% PASS0.88 5.05E-02 0.88 5.30E-02 0.06 7.20E-02 0.06 4.32E-02 0.06 4.32E-02 0.06 9 8-hr ITSL 0.6% PASS0.88 2.12E-03 0.88 2.23E-03 0.06 3.06E-03 0.06 1.94E-03 0.06 1.94E-03 2.38E-03 0.08 annual IRSL 3.0% PASS

Isomers of xylene 1330-20-7 3.13E-03 2.59E-02 2.72E-03 2.70E-02 2.02E-03 3.52E-02 2.02E-03 2.35E-02 2.02E-03 2.34E-02 2.47E-04 100 24-hr ITSL 0.0% PASS 1 (AQD FN 2 )0.05 2.92E-01 0.04 2.95E-01 0.03 3.76E-01 0.03 2.59E-01 0.03 2.59E-01 0.04 280 1-hr ITSL 0.0% PASS0.05 2.12E-03 0.04 2.23E-03 0.03 3.06E-03 0.03 1.94E-03 0.03 1.94E-03 3.24E-04 3.7 annual IRSL 0.0% PASS


Methyl bromide 74-83-9 0.01 2.59E-02 0.01 2.70E-02 8.74E-03 3.52E-02 8.74E-03 2.35E-02 8.74E-03 2.34E-02 1.07E-03 5 24-hr ITSL 0.0% PASS 1 (AQD FN 3 )0.04 2.59E-02 0.04 2.70E-02 0.03 3.52E-02 0.03 2.35E-02 0.03 2.34E-02 3.54E-03 90 24-hr ITSL 0.0% PASS0.04 2.12E-03 0.04 2.23E-03 0.03 3.06E-03 0.03 1.94E-03 0.03 1.94E-03 2.96E-04 1.6 annual IRSL 0.0% PASS

Methyl ethyl ketone 78-93-3 0.03 2.59E-02 0.03 2.70E-02 0.02 3.52E-02 0.02 2.35E-02 0.02 2.34E-02 2.60E-03 5000 24-hr ITSL 0.0% PASS0.01 2.59E-02 0.01 2.70E-02 9.28E-03 3.52E-02 9.28E-03 2.35E-02 9.28E-03 2.34E-02 1.13E-03 0.03 24-hr ITSL 3.8% PASS0.01 2.12E-03 0.01 2.23E-03 9.28E-03 3.06E-03 9.28E-03 1.94E-03 9.28E-03 1.94E-03 9.49E-05 0.0087 annual IRSL 1.1% PASS

Methyl methacrylate 80-62-6 1.69E-03 2.59E-02 1.47E-03 2.70E-02 1.09E-03 3.52E-02 1.09E-03 2.35E-02 1.09E-03 2.34E-02 1.33E-04 700 24-hr ITSL 0.0% PASSN-Hexane 110-54-3 5.67E-03 2.59E-02 4.93E-03 2.70E-02 3.66E-03 3.52E-02 3.66E-03 2.35E-02 3.66E-03 2.34E-02 4.47E-04 700 24-hr ITSL 0.0% PASS

3.64E-03 2.59E-02 3.16E-03 2.70E-02 2.35E-03 3.52E-02 2.35E-03 2.35E-02 2.35E-03 2.34E-02 2.87E-04 40 24-hr ITSL 0.0% PASS3.64E-03 2.12E-03 3.16E-03 2.23E-03 2.35E-03 3.06E-03 2.35E-03 1.94E-03 2.35E-03 1.94E-03 2.40E-05 4 annual IRSL 0.0% PASS

Phenol 108-95-2 1.35E-03 2.92E-01 1.18E-03 2.95E-01 8.74E-04 3.76E-01 8.74E-04 2.59E-01 8.74E-04 2.59E-01 1.18E-03 600 1-hr ITSL 0.0% PASSPropionaldehyde 123-38-6 0.03 2.59E-02 0.03 2.70E-02 0.02 3.52E-02 0.02 2.35E-02 0.02 2.34E-02 2.54E-03 8 24-hr ITSL 0.0% PASSPyrene 129-00-0 2.79E-05 2.59E-02 2.43E-05 2.70E-02 1.80E-05 3.52E-02 1.80E-05 2.35E-02 1.80E-05 2.34E-02 2.20E-06 100 24-hr ITSL 0.0% PASS

Pass/Fail FootNotePAI

(µg/m3)

Screening Level

(µg/m3)

AveragingPeriod (µg/m3)

BasisPercent of Screening

Level

Boiler 8 Boiler 9BOILERS_8_9 BOILERS_8_9

Hydrogen chloride

Boilers_ 5_6_995 Boilers_ 5_6_680 Boiler 7BOILER_5_6 BOILER_5_6 BOILER_7

Toxic Air Contaminant CAS No.

Acrolein 107-02-8 1 (AQD FN 13 )

1 (AQD FN 13 )7647-01-0

Hydrogen fluoride 7664-39-3 1 (AQD FN 13 )

Acetaldehyde 75-07-0

2,4-Dinitrotoluene 121-14-2

Sulfuric Acid 7664-93-9

Isophorone 78-59-1

Ethylbenzene 100-41-4

Ethylene dibromide 106-93-4

71-43-2

Dichloromethane 75-09-2

Formaldehyde 50-00-0

Benzene

Methyl hydrazine 60-34-4

Isopropylbenzene 98-82-8

Methyl chloride 74-87-3


1 (AQD FN 9,13)

Perchloroethylene 127-18-4


of 2

Table 16 - Maximum Potential Ambient ImpactsAir Use Permit to Install AQCS Retrofit PIPP

Emissions (lb/hr)


Emissions (lb/hr)


Emissions (lb/hr)


Emissions (lb/hr)


Emissions (lb/hr)


Pass/Fail FootNotePAI

(µg/m3)

Screening Level

(µg/m3)

AveragingPeriod (µg/m3)

BasisPercent of Screening

Level

Boiler 8 Boiler 9BOILERS_8_9 BOILERS_8_9

Boilers_ 5_6_995 Boilers_ 5_6_680 Boiler 7BOILER_5_6 BOILER_5_6 BOILER_7

Toxic Air Contaminant CAS No.



Tert-butyl methyl ether 1634-04-4 2.96E-03 2.59E-02 2.57E-03 2.70E-02 1.91E-03 3.52E-02 1.91E-03 2.35E-02 1.91E-03 2.34E-02 2.34E-04 3000 24-hr ITSL 0.0% PASSToluene 108-88-3 0.02 2.59E-02 0.02 2.70E-02 0.01 3.52E-02 0.01 2.35E-02 0.01 2.34E-02 1.60E-03 5000 24-hr ITSL 0.0% PASSVinyl acetate 108-05-4 6.44E-04 2.59E-02 5.59E-04 2.70E-02 4.15E-04 3.52E-02 4.15E-04 2.35E-02 4.15E-04 2.34E-02 5.07E-05 200 24-hr ITSL 0.0% PASSMetalsAntimony 7440-36-0 1.52E-03 2.59E-02 1.32E-03 2.70E-02 9.83E-04 3.52E-02 9.83E-04 2.35E-02 9.83E-04 2.34E-02 1.20E-04 0.2 24-hr ITSL 0.1% PASSArsenic 7440-38-2 3.5E-02 2.12E-03 3.0E-02 2.23E-03 2.2E-02 3.06E-03 2.2E-02 1.94E-03 2.2E-02 1.94E-03 2.29E-04 0.002 annual SRSL 11.4% PASS

1.78E-03 2.59E-02 1.54E-03 2.70E-02 1.15E-03 3.52E-02 1.15E-03 2.35E-02 1.15E-03 2.34E-02 1.40E-04 0.02 24-hr ITSL 0.7% PASS

Cadmium 7440-43-9 4.32E-03 2.12E-03 3.75E-03 2.23E-03 2.78E-03 3.06E-03 2.78E-03 1.94E-03 2.78E-03 1.94E-03 2.85E-05 0.0006 annual IRSL 4.7% PASSChromium (III) 7440-47-3 0.02 2.59E-02 0.02 2.70E-02 0.01 3.52E-02 0.01 2.35E-02 0.01 2.34E-02 1.73E-03 0.008 24-hr ITSL 21.7% PASS


Cobalt 7440-48-4 8.47E-03 5.05E-02 7.35E-03 5.30E-02 5.46E-03 7.20E-02 5.46E-03 4.32E-02 5.46E-03 4.32E-02 1.29E-03 0.2 8-hr ITSL 0.6% PASSCopper 7440-50-8 1.58E-06 5.05E-02 1.58E-06 5.30E-02 1.01E-06 7.20E-02 1.01E-06 4.32E-02 1.01E-06 4.32E-02 2.44E-07 2 8-hr ITSL 0.0% PASSLead 7439-92-1 0.04 2.12E-03 0.03 2.23E-03 0.02 3.06E-03 0.02 1.94E-03 0.02 1.94E-03 2.35E-04 0.1 annual TRACE* 0.2% PASSMagnesium 7439-95-4 0.93 5.05E-02 0.81 5.30E-02 0.60 7.20E-02 0.60 4.32E-02 0.60 4.32E-02 0.14 100 8-hr ITSL 0.1% PASSManganese 7439-96-5 0.04 2.12E-03 0.04 2.23E-03 0.03 3.06E-03 0.03 1.94E-03 0.03 1.94E-03 2.74E-04 0.05 annual ITSL 0.5% PASSNickel 7440-02-0 0.02 2.12E-03 0.02 2.23E-03 0.02 3.06E-03 0.02 1.94E-03 0.02 1.94E-03 1.56E-04 0.0042 annual IRSL 3.7% PASSSelenium 7782-49-2 0.11 5.05E-02 0.10 5.30E-02 0.07 7.20E-02 0.07 4.32E-02 0.07 4.32E-02 0.02 2 8-hr ITSL 0.8% PASSZinc 7440-66-6 1.06E-06 5.05E-02 1.06E-06 5.30E-02 6.72E-07 7.20E-02 6.72E-07 4.32E-02 6.72E-07 4.32E-02 1.62E-07 50 8-hr ITSL 0.0% PASS 2PAHsAcenaphthene 83-32-9 4.32E-05 2.59E-02 3.75E-05 2.70E-02 2.78E-05 3.52E-02 2.78E-05 2.35E-02 2.78E-05 2.34E-02 3.40E-06 210 24-hr ITSL 0.0% PASSAcenaphthylene 208-96-8 2.12E-05 2.59E-02 1.84E-05 2.70E-02 1.36E-05 3.52E-02 1.36E-05 2.35E-02 1.36E-05 2.34E-02 1.67E-06 35 24-hr ITSL 0.0% PASSAnthracene 120-12-7 1.78E-05 2.59E-02 1.54E-05 2.70E-02 1.15E-05 3.52E-02 1.15E-05 2.35E-02 1.15E-05 2.34E-02 1.40E-06 1000 24-hr ITSL 0.0% PASS7-carcinogenic PAHs 50-32-8 2.23E-05 2.12E-03 2.23E-05 2.23E-03 3.57E-06 3.06E-03 3.57E-06 1.94E-03 3.57E-06 1.94E-03 7.44E-08 0.0005 annual IRSL 0.0% PASS 1 (AQD FN 5 )Benzo (g,h,i) perylene 191-24-2 2.29E-06 2.59E-02 1.98E-06 2.70E-02 1.47E-06 3.52E-02 1.47E-06 2.35E-02 1.47E-06 2.34E-02 1.80E-07 12 24-hr ITSL 0.0% PASSBiphenyl 92-52-4 1.44E-04 5.05E-02 1.25E-04 5.30E-02 9.28E-05 7.20E-02 9.28E-05 4.32E-02 9.28E-05 4.32E-02 2.20E-05 15 8-hr ITSL 0.0% PASS 1 (AQD FN 21 )Fluoranthene 206-44-0 6.01E-05 2.59E-02 5.22E-05 2.70E-02 3.88E-05 3.52E-02 3.88E-05 2.35E-02 3.88E-05 2.34E-02 4.74E-06 140 24-hr ITSL 0.0% PASSFluorene 86-73-7 7.71E-05 2.59E-02 6.69E-05 2.70E-02 4.97E-05 3.52E-02 4.97E-05 2.35E-02 4.97E-05 2.34E-02 6.07E-06 140 24-hr ITSL 0.0% PASS


Phenanthrene 85-01-8 2.29E-04 2.12E-03 1.98E-04 2.23E-03 1.47E-04 3.06E-03 1.47E-04 1.94E-03 1.47E-04 1.94E-03 1.51E-06 0.1 annual ITSL 0.0% PASSDioxins/Furans

1.64E-08 2.12E-03 1.64E-08 2.23E-03 1.06E-08 3.06E-03 1.06E-08 1.94E-03 1.06E-08 1.94E-03 1.10E-10 0.000002 annual ITSL 0.0% PASS1.64E-08 2.12E-03 1.64E-08 2.23E-03 1.06E-08 3.06E-03 1.06E-08 1.94E-03 1.06E-08 1.94E-03 1.10E-10 2.3E-08 annual IRSL 0.5% PASS

1 AQD Footnotes:

AQD 3-These chemicals are very likely to meet the R 336.1103(c) definition of a carcinogen. The Air Quality Division has not evaluated the data to develop an IRSL/SRSL.

2 Screening Level for Zinc oxide (1314-13-2) was used.

AQD 21 - This chemical is very likely to meet the R336.1103(c) definition of a carcinogen. The Air Quality Division has evaluated the data and determined it to be inadequate forIRSL/SRSL development. However, the ITSL provides adequate protection against potential cancer effects.

AQD 9 - This chemical meets the definition of a carcinogen per Rule 336.1103(c), but risk management considerations indicate that no IRSL should be derived. The combined ambient impacts of sulfuric acid, sulfur trioxide and oleum cannot exceed the ITSLs. AQD 13 - This chemical has two ITSLs with different averaging times. Ambient air impacts cannot exceed either ITSL. Both ITSLs also apply for determinations of permit to install exemptions under R336.1290 (Rule 290).

AQD 5 - The seven carcinogenic polycyclic aromatic hydrocarbons (PAHs) should be evaluated additively utilizing the comparative potency estimates approved by the AQD Scientific Advisory Panel (July 20, 1995), compared to the screening level for benzo(a)pyrene (CAS # 50-32-8).

Relative 2,3,7,8-TCDD based on TEF

1746-01-6

AQD 2 - The combined ambient impact of all forms of xylene with Note #2 cannot exceed the initial threshold screening level (ITSL) of 100 μg/m3 (24-hour average).

Naphthalene 91-20-3

Chromium (VI) 18540-29-9

Styrene 100-42-5

Beryllium 7440-41-7


Appendix 1

July 2, 2012, DRAFT

Page 1 of 93

MICHIGAN DEPARTMENT OF ENVIRONMENTAL QUALITY

AIR QUALITY DIVISION

EFFECTIVE DATE: January 1, 201X

ISSUED TO

Wisconsin Electric Power Company Presque Isle Power Plant

State Registration Number (SRN): B4261

LOCATED AT

2701 N. Lakeshore Boulevard, Marquette, Michigan 49855

RENEWABLE OPERATING PERMIT

Permit Number: MI-ROP-B4261-201X

Expiration Date:

Administratively Complete ROP Renewal Application Due Between XXXX and XXXX

This Renewable Operating Permit (ROP) is issued in accordance with and subject to Section 5506(3) of Part 55, Air Pollution Control, of the Natural Resources and Environmental Protection Act, 1994 PA 451, as amended (Act 451). Pursuant to Michigan Air Pollution Control Rule 210(1), this ROP constitutes the permittee’s authority to operate the stationary source identified above in accordance with the general conditions, special conditions and attachments contained herein. Operation of the stationary source and all emission units listed in the permit are subject to all applicable future or amended rules and regulations pursuant to Act 451 and the federal Clean Air Act.

SOURCE-WIDE PERMIT TO INSTALL

Permit Number: MI-PTI-B4261-201X

This Permit to Install (PTI) is issued in accordance with and subject to Section 5505(5) of Act 451. Pursuant to Michigan Air Pollution Control Rule 214a, the terms and conditions herein, identified by the underlying applicable requirement citation of Rule 201(1)(a), constitute a federally enforceable PTI. The PTl terms and conditions do not expire and remain in effect unless the criteria of Rule 201(6) are met. Operation of all emission units identified in the PTI is subject to all applicable future or amended rules and regulations pursuant to Act 451 and the federal Clean Air Act.

Michigan Department of Environmental Quality ______________________________________ Chris Hare, A/Upper Peninsula District Supervisor

Wisconsin Electric Power Co. ROP No.: MI-ROP-B4261-201X

Presque Isle Power Plant July 2, 2012, DRAFT Expiration Date:

PTI No.: MI-PTI-B4261-201X

Page 2 of 93

TABLE OF CONTENTS

AUTHORITY AND ENFORCEABILITY ................................................................................................... 3

A. GENERAL CONDITIONS................................................................................................................... 4

Permit Enforceability ................................................................................................................................ 4 General Provisions ................................................................................................................................... 4 Equipment & Design ................................................................................................................................ 5 Emission Limits ........................................................................................................................................ 5 Testing/Sampling ..................................................................................................................................... 5 Monitoring/Recordkeeping ....................................................................................................................... 6 Certification & Reporting .......................................................................................................................... 6 Permit Shield ........................................................................................................................................... 7 Revisions ................................................................................................................................................. 8 Reopenings .............................................................................................................................................. 8 Renewals ................................................................................................................................................. 9 Stratospheric Ozone Protection ............................................................................................................... 9 Risk Management Plan ............................................................................................................................ 9 Emission Trading ..................................................................................................................................... 9 Permit To Install (PTI) ............................................................................................................................ 10

B. SOURCE-WIDE CONDITIONS ........................................................................................................ 11

C. EMISSION UNIT CONDITIONS ....................................................................................................... 18

EMISSION UNIT SUMMARY TABLE ..................................................................................................... 18 EUBOILER5 ........................................................................................................................................... 22 EUBOILER6 ........................................................................................................................................... 28 EUBOILER7 ........................................................................................................................................... 33 EUBOILER8 ........................................................................................................................................... 39 EUBOILER9 ........................................................................................................................................... 45 EUASHHANDLING ................................................................................................................................ 51 EUMATERIALHANDLING ...................................................................................................................... 53 EUICDIESEL2 ....................................................................................................................................... 56

D. FLEXIBLE GROUP CONDITIONS ................................................................................................... 58

FLEXIBLE GROUP SUMMARY TABLE ................................................................................................. 58 FGICDIESELS ....................................................................................................................................... 59

E. NON-APPLICABLE REQUIREMENTS ............................................................................................ 62

APPENDICES ....................................................................................................................................... 63

Appendix 1. Abbreviations and Acronyms ............................................................................................. 63 Appendix 2. Schedule of Compliance .................................................................................................... 64 Appendix 3. Monitoring Requirements .................................................................................................. 64 Appendix 4. Recordkeeping .................................................................................................................. 64 Appendix 5. Testing Procedures ........................................................................................................... 64 Appendix 6. Permits to Install ................................................................................................................ 64 Appendix 7. Emission Calculations ....................................................................................................... 64 Appendix 8. Reporting .......................................................................................................................... 65 Appendix 9. Phase II Acid Rain Permit ................................................................................................. 66 Appendix 12. CAIR Ozone Nitrogen Oxide Budget Permit ................................................................... 91




Page 3 of 93

AUTHORITY AND ENFORCEABILITY For the purpose of this permit, the permittee is defined as any person who owns or operates an emission unit at a stationary source for which this permit has been issued. The department is defined in Rule 104(d) as the Director of the Michigan Department of Environmental Quality (MDEQ) or his or her designee. The permittee shall comply with all specific details in the permit terms and conditions and the cited underlying applicable requirements. All terms and conditions in this ROP are both federally enforceable and state enforceable unless otherwise footnoted. Certain terms and conditions are applicable to most stationary sources for which an ROP has been issued. These general conditions are included in Part A of this ROP. Other terms and conditions may apply to a specific emission unit, several emission units which are represented as a flexible group, or the entire stationary source which is represented as a Source-Wide group. Special conditions are identified in Parts B, C, D and/or the appendices. In accordance with Rule 213(2)(a), all underlying applicable requirements will be identified for each ROP term or condition. All terms and conditions that are included in a PTI, are streamlined or subsumed, or are state only enforceable will be noted as such. In accordance with Section 5507 of Act 451, the permittee has included in the ROP application a compliance certification, a schedule of compliance, and a compliance plan. For applicable requirements with which the source is in compliance, the source will continue to comply with these requirements. For applicable requirements with which the source is not in compliance, the source will comply with the detailed schedule of compliance requirements that are incorporated as an appendix in this ROP. Furthermore, for any applicable requirements effective after the date of issuance of this ROP, the stationary source will meet the requirements on a timely basis, unless the underlying applicable requirement requires a more detailed schedule of compliance. Issuance of this permit does not obviate the necessity of obtaining such permits or approvals from other units of government as required by law.




Page 4 of 93

A. GENERAL CONDITIONS

Permit Enforceability

All conditions in this permit are both federally enforceable and state enforceable unless otherwise noted. (R 336.1213(5))

Those conditions that are hereby incorporated in a state-only enforceable Source-Wide PTI pursuant to Rule 201(2)(d) are designated by footnote one. (R 336.1213(5)(a), R 336.1214a(5))

Those conditions that are hereby incorporated in federally enforceable Source-Wide PTI No. MI-PTI-B4261- pursuant to Rule 201(2)(c) are designated by footnote two. (R 336.1213(5)(b), R 336.1214a(3))

General Provisions 1. The permittee shall comply with all conditions of this ROP. Any ROP noncompliance constitutes a violation of

Act 451, and is grounds for enforcement action, for ROP revocation or revision, or for denial of the renewal of the ROP. All terms and conditions of this ROP that are designated as federally enforceable are enforceable by the Administrator of the United States Environmental Protection Agency (USEPA) and by citizens under the provisions of the federal Clean Air Act (CAA). Any terms and conditions based on applicable requirements which are designated as “state-only” are not enforceable by the USEPA or citizens pursuant to the CAA. (R 336.1213(1)(a))

2. It shall not be a defense for the permittee in an enforcement action that it would have been necessary to halt

or reduce the permitted activity in order to maintain compliance with the conditions of this ROP. (R 336.1213(1)(b))

3. This ROP may be modified, revised, or revoked for cause. The filing of a request by the permittee for a

permit modification, revision, or termination, or a notification of planned changes or anticipated noncompliance does not stay any ROP term or condition. This does not supersede or affect the ability of the permittee to make changes, at the permittee’s own risk, pursuant to Rule 215 and Rule 216. (R 336.1213(1)(c))

4. The permittee shall allow the department, or an authorized representative of the department, upon

presentation of credentials and other documents as may be required by law and upon stating the authority for and purpose of the investigation, to perform any of the following activities: (R 336.1213(1)(d)) a. Enter, at reasonable times, a stationary source or other premises where emissions-related activity is

conducted or where records must be kept under the conditions of the ROP. b. Have access to and copy, at reasonable times, any records that must be kept under the conditions of the

ROP. c. Inspect, at reasonable times, any of the following:

i. Any stationary source. ii. Any emission unit. iii. Any equipment, including monitoring and air pollution control equipment. iv. Any work practices or operations regulated or required under the ROP.

d. As authorized by Section 5526 of Act 451, sample or monitor at reasonable times substances or parameters for the purpose of assuring compliance with the ROP or applicable requirements.

5. The permittee shall furnish to the department, within a reasonable time, any information the department may

request, in writing, to determine whether cause exists for modifying, revising, or revoking the ROP or to determine compliance with this ROP. Upon request, the permittee shall also furnish to the department copies of any records that are required to be kept as a term or condition of this ROP. For information which is claimed by the permittee to be confidential, consistent with the requirements of the 1976 PA 442, MCL




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§15.231 et seq., and known as the Freedom of Information Act, the person may also be required to furnish the records directly to the USEPA together with a claim of confidentiality. (R 336.1213(1)(e))

6. A challenge by any person, the Administrator of the USEPA, or the department to a particular condition or a

part of this ROP shall not set aside, delay, stay, or in any way affect the applicability or enforceability of any other condition or part of this ROP. (R 336.1213(1)(f))

7. The permittee shall pay fees consistent with the fee schedule and requirements pursuant to Section 5522 of

Act 451. (R 336.1213(1)(g)) 8. This ROP does not convey any property rights or any exclusive privilege. (R 336.1213(1)(h))

Equipment & Design 9. Any collected air contaminants shall be removed as necessary to maintain the equipment at the required

operating efficiency. The collection and disposal of air contaminants shall be performed in a manner so as to minimize the introduction of contaminants to the outer air. Transport of collected air contaminants in Priority I and II areas requires the use of material handling methods specified in Rule 370(2). (R 336.1370)

10. Any air cleaning device shall be installed, maintained, and operated in a satisfactory manner and in

accordance with the Michigan Air Pollution Control rules and existing law. (R 336.1910)

Emission Limits 11. Except as provided in Subrules 2, 3, and 4 of Rule 301, states in part; “a person shall not cause or permit to

be discharged into the outer air from a process or process equipment a visible emission of a density greater than the most stringent of Rule 301(1)(a) or (b) unless otherwise specified in this ROP.” The grading of visible emissions shall be determined in accordance with Rule 303. (R 336.1301(1) in pertinent part): a. A 6-minute average of 20 percent opacity, except for one 6-minute average per hour of not more than 27

percent opacity. b. A limit specified by an applicable federal new source performance standard.

12. The permittee shall not cause or permit the emission of an air contaminant or water vapor in quantities that cause,

alone or in reaction with other air contaminants, either of the following: a. Injurious effects to human health or safety, animal life, plant life of significant economic value, or property.

1 (R 336.1901(a))

b. Unreasonable interference with the comfortable enjoyment of life and property.1 (R 336.1901(b))

Testing/Sampling 13. The department may require the owner or operator of any source of an air contaminant to conduct acceptable

performance tests, at the owner’s or operator’s expense, in accordance with Rule 1001 and Rule 1003, under any of the conditions listed in Rule 1001(1). (R 336.2001)

14. Any required performance testing shall be conducted in accordance with Rule 1001(2), Rule 1001(3) and

Rule 1003. (R 336.2001(2), R 336.2001(3), R 336.2003(1)) 15. Any required test results shall be submitted to the Air Quality Division (AQD) in the format prescribed by the

applicable reference test method within 60 days following the last date of the test. (R 336.2001(4))




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Monitoring/Recordkeeping 16. Records of any periodic emission or parametric monitoring required in this ROP shall include the following

information specified in Rule 213(3)(b)(i), where appropriate: (R 336.1213(3)(b)) a. The date, location, time, and method of sampling or measurements. b. The dates the analyses of the samples were performed. c. The company or entity that performed the analyses of the samples. d. The analytical techniques or methods used. e. The results of the analyses. f. The related process operating conditions or parameters that existed at the time of sampling or

measurement. 17. All required monitoring data, support information and all reports, including reports of all instances of deviation

from permit requirements, shall be kept and furnished to the department upon request for a period of not less than 5 years from the date of the monitoring sample, measurement, report or application. Support information includes all calibration and maintenance records and all original strip-chart recordings, or other original data records, for continuous monitoring instrumentation and copies of all reports required by the ROP. (R 336.1213(1)(e), R 336.1213(3)(b)(ii))

Certification & Reporting 18. Except for the alternate certification schedule provided in Rule 213(3)(c)(iii)(B), any document required to be

submitted to the department as a term or condition of this ROP shall contain an original certification by a Responsible Official which states that, based on information and belief formed after reasonable inquiry, the statements and information in the document are true, accurate, and complete. (R 336.1213(3)(c))

19. A Responsible Official shall certify to the appropriate AQD District Office and to the USEPA that the stationary

source is and has been in compliance with all terms and conditions contained in the ROP except for deviations that have been or are being reported to the appropriate AQD District Office pursuant to Rule 213(3)(c). This certification shall include all the information specified in Rule 213(4)(c)(i) through (v) and shall state that, based on information and belief formed after reasonable inquiry, the statements and information in the certification are true, accurate, and complete. The USEPA address is: USEPA, Air Compliance Data - Michigan, Air and Radiation Division, 77 West Jackson Boulevard, Chicago, Illinois 60604. (R 336.1213(4)(c))

20. The certification of compliance shall be submitted annually for the term of this ROP as detailed in the special

conditions, or more frequently if specified in an applicable requirement or in this ROP. (R 336.1213(4)(c)) 21. The permittee shall promptly report any deviations from ROP requirements and certify the reports. The

prompt reporting of deviations from ROP requirements is defined in Rule 213(3)(c)(ii) as follows, unless otherwise described in this ROP. (R 336.1213(3)(c)) a. For deviations that exceed the emissions allowed under the ROP, prompt reporting means reporting

consistent with the requirements of Rule 912 as detailed in Condition 25. All reports submitted pursuant to this paragraph shall be promptly certified as specified in Rule 213(3)(c)(iii).

b. For deviations which exceed the emissions allowed under the ROP and which are not reported pursuant to Rule 912 due to the duration of the deviation, prompt reporting means the reporting of all deviations in the semiannual reports required by Rule 213(3)(c)(i). The report shall describe reasons for each deviation and the actions taken to minimize or correct each deviation.

c. For deviations that do not exceed the emissions allowed under the ROP, prompt reporting means the reporting of all deviations in the semiannual reports required by Rule 213(3)(c)(i). The report shall describe the reasons for each deviation and the actions taken to minimize or correct each deviation.




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22. For reports required pursuant to Rule 213(3)(c)(ii), prompt certification of the reports is described in

Rule 213(3)(c)(iii) as either of the following: (R 336.1213(3)(c)) a. Submitting a certification by a Responsible Official with each report which states that, based on

information and belief formed after reasonable inquiry, the statements and information in the report are true, accurate, and complete.

b. Submitting, within 30 days following the end of a calendar month during which one or more prompt reports of deviations from the emissions allowed under the ROP were submitted to the department pursuant to Rule 213(3)(c)(ii), a certification by a Responsible Official which states that, “based on information and belief formed after reasonable inquiry, the statements and information contained in each of the reports submitted during the previous month were true, accurate, and complete”. The certification shall include a listing of the reports that are being certified. Any report submitted pursuant to Rule 213(3)(c)(ii) that will be certified on a monthly basis pursuant to this paragraph shall include a statement that certification of the report will be provided within 30 days following the end of the calendar month.

23. Semiannually for the term of the ROP as detailed in the special conditions, or more frequently if specified, the

permittee shall submit certified reports of any required monitoring to the appropriate AQD District Office. All instances of deviations from ROP requirements during the reporting period shall be clearly identified in the reports. (R 336.1213(3)(c)(i))

24. On an annual basis, the permittee shall report the actual emissions, or the information necessary to determine

the actual emissions, of each regulated air pollutant as defined in Rule 212(6) for each emission unit utilizing the emissions inventory forms provided by the department. (R 336.1212(6))

25. The permittee shall provide notice of an abnormal condition, start-up, shutdown, or malfunction that results in

emissions of a hazardous or toxic air pollutant which continue for more than one hour in excess of any applicable standard or limitation, or emissions of any air contaminant continuing for more than two hours in excess of an applicable standard or limitation, as required in Rule 912, to the appropriate AQD District Office. The notice shall be provided not later than two business days after the start-up, shutdown, or discovery of the abnormal conditions or malfunction. Notice shall be by any reasonable means, including electronic, telephonic, or oral communication. Written reports, if required under Rule 912, must be submitted to the appropriate AQD District Supervisor within 10 days after the start-up or shutdown occurred, within 10 days after the abnormal conditions or malfunction has been corrected, or within 30 days of discovery of the abnormal conditions or malfunction, whichever is first. The written reports shall include all of the information required in Rule 912(5) and shall be certified by a Responsible Official in a manner consistent with the CAA. (R 336.1912)

Permit Shield 26. Compliance with the conditions of the ROP shall be considered compliance with any applicable requirements

as of the date of ROP issuance, if either of the following provisions is satisfied. (R 336.1213(6)(a)(i), R 336.1213(6)(a)(ii)) a. The applicable requirements are included and are specifically identified in the ROP. b. The permit includes a determination or concise summary of the determination by the department that

other specifically identified requirements are not applicable to the stationary source.

Any requirements identified in Part E of this ROP have been identified as non-applicable to this ROP and are included in the permit shield.

27. Nothing in this ROP shall alter or affect any of the following:

a. The provisions of Section 303 of the CAA, emergency orders, including the authority of the USEPA under Section 303 of the CAA. (R 336.1213(6)(b)(i))

b. The liability of the owner or operator of this source for any violation of applicable requirements prior to or at the time of this ROP issuance. (R 336.1213(6)(b)(ii))

c. The applicable requirements of the acid rain program, consistent with Section 408(a) of the CAA. (R 336.1213(6)(b)(iii))




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d. The ability of the USEPA to obtain information from a source pursuant to Section 114 of the CAA. (R 336.1213(6)(b)(iv))

28. The permit shield shall not apply to provisions incorporated into this ROP through procedures for any of the

following: a. Operational flexibility changes made pursuant to Rule 215. (R 336.1215(5)) b. Administrative Amendments made pursuant to Rule 216(1)(a)(i)-(iv). R 336.1216(1)(b)(iii)) c. Administrative Amendments made pursuant to Rule 216(1)(a)(v) until the amendment has been approved

by the department. (R 336.1216(1)(c)(iii)) d. Minor Permit Modifications made pursuant to Rule 216(2). (R 336.1216(2)(f)) e. State-Only Modifications made pursuant to Rule 216(4) until the changes have been approved by the

department. (R 336.1216(4)(e)) 29. Expiration of this ROP results in the loss of the permit shield. If a timely and administratively complete

application for renewal is submitted not more than 18 months, but not less than 6 months, before the expiration date of the ROP, but the department fails to take final action before the end of the ROP term, the existing ROP does not expire until the renewal is issued or denied, and the permit shield shall extend beyond the original ROP term until the department takes final action. (R 336.1217(1)(c), R 336.1217(1)(a))

Revisions 30. For changes to any process or process equipment covered by this ROP that do not require a revision of the

ROP pursuant to Rule 216, the permittee must comply with Rule 215. (R 336.1215, R 336.1216) 31. A change in ownership or operational control of a stationary source covered by this ROP shall be made pursuant

to Rule 216(1). (R 336.1219(2)) 32. For revisions to this ROP, an administratively complete application shall be considered timely if it is received

by the department in accordance with the time frames specified in Rule 216. (R 336.1210(9)) 33. Pursuant to Rule 216(1)(b)(iii), Rule 216(2)(d) and Rule 216(4)(d), after a change has been made, and until

the department takes final action, the permittee shall comply with both the applicable requirements governing the change and the ROP terms and conditions proposed in the application for the modification. During this time period, the permittee may choose to not comply with the existing ROP terms and conditions that the application seeks to change. However, if the permittee fails to comply with the ROP terms and conditions proposed in the application during this time period, the terms and conditions in the ROP are enforceable. (R 336.1216(1)(c)(iii), R 336.1216(2)(d), R 336.1216(4)(d))

Reopenings 34. A ROP shall be reopened by the department prior to the expiration date and revised by the department under

any of the following circumstances: a. If additional requirements become applicable to this stationary source with three or more years remaining

in the term of the ROP, but not if the effective date of the new applicable requirement is later than the ROP expiration date. (R 336.1217(2)(a)(i))

b. If additional requirements pursuant to Title IV of the CAA become applicable to this stationary source. (R 336.1217(2)(a)(ii))

c. If the department determines that the ROP contains a material mistake, information required by any applicable requirement was omitted, or inaccurate statements were made in establishing emission limits or the terms or conditions of the ROP. (R 336.1217(2)(a)(iii))

d. If the department determines that the ROP must be revised to ensure compliance with the applicable requirements. (R 336.1217(2)(a)(iv))




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Renewals 35. For renewal of this ROP, an administratively complete application shall be considered timely if it is received

by the department not more than 18 months, but not less than 6 months, before the expiration date of the ROP. (R 336.1210(7))

Stratospheric Ozone Protection 36. If the permittee is subject to Title 40 of the Code of Federal Regulations (CFR), Part 82 and services,

maintains, or repairs appliances except for motor vehicle air conditioners (MVAC), or disposes of appliances containing refrigerant, including MVAC and small appliances, or if the permittee is a refrigerant reclaimer, appliance owner or a manufacturer of appliances or recycling and recovery equipment, the permittee shall comply with all applicable standards for recycling and emissions reduction pursuant to 40 CFR, Part 82, Subpart F.

37. If the permittee is subject to 40 CFR, Part 82, and performs a service on motor (fleet) vehicles when this

service involves refrigerant in the MVAC, the permittee is subject to all the applicable requirements as specified in 40 CFR, Part 82, Subpart B, Servicing of Motor Vehicle Air Conditioners. The term “motor vehicle” as used in Subpart B does not include a vehicle in which final assembly of the vehicle has not been completed by the original equipment manufacturer. The term MVAC as used in Subpart B does not include the air-tight sealed refrigeration system used for refrigerated cargo or an air conditioning system on passenger buses using Hydrochlorofluorocarbon-22 refrigerant.

Risk Management Plan 38. If subject to Section 112(r) of the CAA and 40 CFR, Part 68, the permittee shall register and submit to the

USEPA the required data related to the risk management plan for reducing the probability of accidental releases of any regulated substances listed pursuant to Section 112(r)(3) of the CAA as amended in 40 CFR, Part 68.130. The list of substances, threshold quantities, and accident prevention regulations promulgated under 40 CFR, Part 68, do not limit in any way the general duty provisions under Section 112(r)(1).

39. If subject to Section 112(r) of the CAA and 40 CFR, Part 68, the permittee shall comply with the requirements

of 40 CFR, Part 68, no later than the latest of the following dates as provided in 40 CFR, Part 68.10(a): a. June 21, 1999, b. Three years after the date on which a regulated substance is first listed under 40 CFR, Part 68.130, or c. The date on which a regulated substance is first present above a threshold quantity in a process.

40. If subject to Section 112(r) of the CAA and 40 CFR, Part 68, the permittee shall submit any additional relevant

information requested by any regulatory agency necessary to ensure compliance with the requirements of 40 CFR, Part 68.

41. If subject to Section 112(r) of the CAA and 40 CFR, Part 68, the permittee shall annually certify compliance

with all applicable requirements of Section 112(r) as detailed in Rule 213(4)(c)). (40 CFR, Part 68)

Emission Trading 42. Emission averaging and emission reduction credit trading are allowed pursuant to any applicable interstate or

regional emission trading program that has been approved by the Administrator of the USEPA as a part of Michigan’s State Implementation Plan. Such activities must comply with Rule 215 and Rule 216. (R 336.1213(12))




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Permit To Install (PTI) 43. The process or process equipment included in this permit shall not be reconstructed, relocated, or modified

unless a PTI authorizing such action is issued by the department, except to the extent such action is exempt from the PTI requirements by any applicable rule.

2 (R 336.1201(1)) 44. The department may, after notice and opportunity for a hearing, revoke PTI terms or conditions if evidence

indicates the process or process equipment is not performing in accordance with the terms and conditions of the PTI or is violating the department’s rules or the CAA.

2 (R 336.1201(8), Section 5510 of Act 451) 45. The terms and conditions of a PTI shall apply to any person or legal entity that now or hereafter owns or

operates the process or process equipment at the location authorized by the PTI. If a new owner or operator submits a written request to the department pursuant to Rule 219 and the department approves the request, this PTI will be amended to reflect the change of ownership or operational control. The request must include all of the information required by Subrules (1)(a), (b) and (c) of Rule 219. The written request shall be sent to the appropriate AQD District Supervisor, MDEQ.

2 (R 336.1219) 46. If the installation, reconstruction, relocation, or modification of the equipment for which PTI terms and

conditions have been approved has not commenced within 18 months, or has been interrupted for 18 months, the applicable terms and conditions from that PTI shall become void unless otherwise authorized by the department. Furthermore, the person to whom that PTI was issued, or the designated authorized agent, shall notify the department via the Supervisor, Permit Section, MDEQ, AQD, P. O. Box 30260, Lansing, Michigan 48909, if it is decided not to pursue the installation, reconstruction, relocation, or modification of the equipment allowed by the terms and conditions from that PTI.

2 (R 336.1201(4)) Footnotes: 1This condition is state only enforceable and was established pursuant to Rule 201(1)(b).

2This condition is federally enforceable and was established pursuant to Rule 201(1)(a).




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B. SOURCE-WIDE CONDITIONS Part B outlines the Source-Wide Terms and Conditions that apply to this stationary source. The permittee is subject to these special conditions for the stationary source in addition to the general conditions in Part A and any other terms and conditions contained in this ROP. The permittee shall comply with all specific details in the special conditions and the underlying applicable requirements cited. If a specific condition type does not apply to this source, NA (not applicable) has been used in the table. If there are no Source-Wide Conditions, this section will be left blank.

A. Consent Decree Definitions

Improved Unit “Improved Unit” means in the case of NOx, a Wisconsin Electric System Unit scheduled under the Consent Decree to be equipped with SCR (or equivalent NOx control technology as approved per Civil Action No. 03-C-0371 Paragraph 59) or to be retired, and in the case of SO2, a Wisconsin Electric System Unit scheduled under the Decree to be equipped with an FGD (or equivalent SO2 control technology as approved per Civil Action No. 03-C-0371 Paragraph 74) or to be retired. A Unit may be an Improved Unit for one pollutant without being an Improved Unit for the other. (Improved Units include Pleasant Prairie Power Plant Units 1 and 2, Presque Isle Power Plant Units 3 & 4, and Oak Creek Power Plant Units 5-8.) (Civil Action No. 03-C-0371 Paragraph 21)

Other Unit “Other Unit” means any Unit of the Wisconsin Electric System that is not an Improved Unit for the pollutant in question. A Unit may be an Improved Unit for NOx and an Other Unit for SO2 and vice versa. (Other Units include Valley Power Plant Units 1-4 and Presque Isle Power Plant Units 5-9.) (Civil Action No. 03-C-0371 Paragraph 32)

Wisconsin Electric System

“Wisconsin Electric System” means the following twenty-three (23) coal-fired, electric utility steam generating Units (with the rated MW (net) capacity of each Unit noted in parentheses): (Civil Action No. 03-C-0371 Paragraph 56)

Presque Isle Generating Station in Marquette, Michigan – Unit 1 (25MW), Unit 2 (37.5 MW), 3 (54.4 MW), 4 (57.8 MW), 5 (90 MW), 6 (90 MW), 7 (90 MW), 8 (90 MW), and 9 (90 MW);

Pleasant Prairie Generating Station in Kenosha, Wisconsin – Units 1 (616.6 MW) and 2 (616.6 MW);

South Oak Creek Generating Station in Oak Creek, Wisconsin – Units 5 (275 MW), 6 (275 MW), 7 (317.6 MW), and 8 (324 MW);

Port Washington Generating Station in Port Washington (coal units), Wisconsin – Units 1 (80 MW), 2 (80 MW), 3 (80 MW), and 4 (80 MW);

Valley Generating Station in Milwaukee, Wisconsin – Units 1 (80 MW), 2 (80 MW), 3 (80 MW), and 4 (80 MW).

Plant-specific 12-Month Rolling Tonnage

“Plant-specific 12-Month Rolling Tonnage” means the sum of the tons of pollutants in question emitted from the applicable plant in the most recent month and the previous eleven (11) months. A new Plant-specific 12-Month Rolling Tonnage will be calculated for each new complete month. (Civil Action No. 03-C-0371, Paragraph 38)

B. Wisconsin Electric Units to be Controlled or Retired: (Civil Action No. 03-C-0371 Paragraph 57)

Unit Date by which the Permittee Must Control or Cease to Operate Unit Presque Isle Unit 1 December 31, 2012

Presque Isle Unit 2 December 31, 2012






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Note: Presque Isle Unit 1 and Presque Isle Unit 2 were retired on January 1, 2007 and Presque Isle Unit 3 and Presque Isle Unit 4 were retired on October 1, 2009. C. System-Wide Consent Decree Requirements: NOx Related Limitations: 1. The permittee shall not exceed the Wisconsin Electric System-wide 12-Month Rolling Average Emission

Rates or 12-Month Rolling Tonnage basis for NOx as specified below. (Civil Action No. 03-C-0371 Paragraphs 62 and 63)

For the 12-Month Period Commencing on the Date

Specified Below, and Each 12-Month Period Thereafter

System-Wide 12-Month Rolling Average Emission Rate for NOx

System-Wide 12-Month Rolling Tonnage Limitation

for NOx

January 1, 2005 0.270 lb/MMBTU 31,500 tons



2. The permittee shall not use, sell or trade any resulting NOx emission allowances or credits in any emission

trading or marketing program of any kind, except provided by the Decree. (Civil Action No. 03-C-0371 Paragraph 66)

3. NOx emission allowances or credits allocated to the Wisconsin Electric System by the Administrator of EPA

under the Act, or by any State under its State Implementation Plan, may be used the Company to meet its own federal and/or state Clean Air Act regulatory requirements for any existing unit or new unit owned or operated, in whole or in part, by the Company. (Civil Action No. 03-C-0371 Paragraph 67)

4. The permittee may use, sell, or transfer excess NOx emission allowances or credits that may arise as a result

of: (Civil Action No. 03-C-0371 Paragraph 69) a. activities prior to the date of entry of the Decree; b. achieving NOx emission reductions at an improved unit that are below both the 30-day rolling average

emission rate of 0.100 lb/MMBTU NOx and the system-wide 12-month rolling tonnage limitations set forth above; or

c. the NOx emission reductions achieved by virtue of the Company's installation and operation any NOx pollution controls prior to the dates required under Section V of the Decree, so long as the Company timely reports the creation of such allowances or credits in accordance with Section XII of the Decree. For purposes of this requirement, excess NOx emission allowances or credits equal the number of tons of NOx that the Company removed from its emissions that are in excess of the NOx reductions required by the Decree.

5. The permittee may not purchase or otherwise obtain NOx allowances or credits from another source for

purposes of complying with the requirements of the Decree. However, nothing in the Decree prevents the Company from purchasing or otherwise obtaining NOx allowances or credits from another source for purposes of complying with state or federal Clean Air Act requirements to the extent otherwise allowed by the law. (Civil Action No. 03-C-0371 Paragraph 70)

6. In determining emission rates for NOx, the permittee shall use CEMS in accordance with those reference

methods specified in 40 CFR Part 75. (Civil Action No. 03-C-0371 Paragraph 71)

7. In calculating the 30-day rolling average emission rate or system-wide 12-month rolling average emission rate for NOx for a given unit or group of units, the permittee shall not exclude any period of time that the unit(s) is/are in operation, including periods in which any NOx emission control technology of the unit(s) is not in operation. (Civil Action No. 03-C-0371 Paragraph 72)




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8. Starting with the 12-month period ending December 31, 2015, the Presque Isle Power Plant shall meet the Plant-specific 12-Month Rolling Tonnage for NOx of 7,376 Tons. (Civil Action No. 03-C-0371 Paragraph 174)

SO2 Related Limitations 1. The permittee shall not exceed the System-Wide 12-Month Rolling Emission Rates, as specified below, and

shall not emit SO2 on a System-Wide 12-Month Rolling Tonnage basis in an amount greater than the following number of tons. The permittee shall meet the SO2 tonnage limitations exclusively through the operation of all control equipment required to be installed and operated by the Decree, Unit retirements, and any additional control equipment the permittee installs and operates. The permittee shall not use SO2 allowances or credits to comply with these limitations. (Civil Action No. 03-C-0371 Paragraphs 76 and 77)

For the 12-Month Period

Commencing on the Date Specified Below, and Each 12-Month Period

Thereafter:

System-wide 12-Month Rolling Average Emission Rate for SO2

System-wide 12-Month Rolling Tonnage Limit for

SO2

January 1, 2007 0.61 lb/MMBTU 74,400 tons January 1, 2008 0.45 lb/MMBTU 55,400 tons January 1, 2013 0.32 lb/MMBTU 33,300 tons

2. The permittee shall comply with the SO2 allowance trading restrictions of the Decree. The "surrender of

allowances" means permanently surrendering allowances from the accounts administered by EPA for all units in the Wisconsin Electric System, so all such allowances can never be used to meet any compliance requirement under the Clean Air Act, the Michigan or Wisconsin State Implementation Plans or the Decree. (Civil Action No. 03-C-0371 Paragraph 78)

3. Beginning on January 1, 2004, the permittee may use any SO2 allowances allocated by EPA to the Wisconsin

Electric System only to satisfy the operational needs of existing units or new units. The permittee shall not sell or transfer any allocated SO2 allowances to a third party, except as provided below. However, for the calendar years 2004 through 2007, the permittee may bank SO2 allowances allocated by EPA to the units in the Wisconsin Electric System for use at the existing units or new units during the years 2004 through 2007. (Civil Action No. 03-C-0371 Paragraph 79)

4. For each calendar year, beginning with calendar year 2007, the permittee shall surrender to EPA, or transfer

to a non-profit third party selected by the Company for surrender, any SO2 allowances that exceed the operational needs of the existing units and new units for SO2 allowances, collectively. Surrender shall occur annually thereafter and within 45 days of the Company's receipt from EPA of the Annual Deduction Reports for SO2. In addition, in calendar year 2008, the permittee shall surrender any allowances allocated by EPA to the units in the Wisconsin Electric System that were banked and not used during the years 2004 through 2007. The permittee shall surrender SO2 allowances by the use of applicable EPA Acid Rain Program Allowance Transfer Form. (Civil Action No. 03-C-0371 Paragraph 80)

5. If any allowances are transferred directly to a third party, the permittee shall include a description of such

transfer in the next report submitted to the Plaintiffs pursuant to Section XII of the Decree. Such report shall:

a. provide the identity of the non-profit third-party recipient(s) of the SO2 allowances and a listing of the serial numbers of the transferred SO2 allowances; and

b. include a certification by the third-party recipient(s) stating that the recipient will not sell, trade, or otherwise exchange any of the allowances and will not use any of the SO2 allowances to meet any obligation imposed by any environmental law.

No later than the next Section XII periodic report due 12 months after the first report due after the transfer, the permittee shall include in a statement that the third-party recipient(s) surrendered the SO2 allowances for permanent surrender to EPA within one year after the permittee transferred the SO2 allowances to them. The permittee shall not have complied with the SO2 allowance surrender requirements of this section until all third-party recipient(s) shall have actually surrendered the transferred SO2 allowances to EPA. (Civil Action No. 03-C-0371 Paragraph 81)




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6. For all SO2 allowances surrendered to EPA, the permittee shall first submit an SO2 allowance transfer request form to EPA's Office of Air and Radiation's Clean Air Markets Division directing the transfer of the SO2 allowances held or controlled by the permittee to the EPA Enforcement Surrender Account or to any other EPA account that EPA may direct. As part of submitting these requests, the permittee shall irrevocably authorize the transfer of the SO2 allowances and identify - by name of account and applicable serial or other identification numbers or station names - the source and location of the SO2 allowances being surrendered. (Civil Action No. 03-C-0371 Paragraph 82)

7. The requirements of the above referenced paragraphs 79 and 80 of the Decree pertaining to the permittee’s

use and retirement of SO2 allowances are permanent injunctions not subject to any termination provision of the Decree. These provisions shall survive any termination of the Decree in whole or in part. (Civil Action No. 03-C-0371 Paragraph 83)

8. Notwithstanding paragraphs 79 and 80, the permittee may use, bank, sell or transfer excess emission SO2

allowances that may arise as a result of: (Civil Action No. 03-C-0371 Paragraph 84) a. activities which occur prior to the date of entry of the Decree; b. achieving SO2 emissions at an improved unit that are below the 30-day rolling average emission rate of

0.100 lb/MMBTU SO2 and system-wide 12-month rolling tonnage limitations set forth in the Decree; or c. the installation and operation of any SO2 pollution controls prior to the dates required under Section VI of

the Decree, so long as the permittee timely reports such use under Section XII of the Decree.

For purposes of this requirement, excess SO2 emission allowances equal the number of tons of SO2 that the permittee removed from its emissions that are in excess of the SO2 reductions required by the Decree.

9. In determining SO2 Emission Rates, the permittee shall use CEMS in accordance with those reference

methods specified in 40 CFR Part 75 and 40 CFR Part 60. (Civil Action No. 03-C-0371 Paragraph 86) 10 For Units that are required to meet a 0.100lb/MMBTU limitation, the SO2 Emission Rate shall be determined

only at the outlet of the control equipment in accordance with 40 CFR §75.15 (using SO2 CEMS data from only the outlet of the control device). (Civil Action No. 03-C-0371 Paragraph 87)

11. Starting with the 12 month period ending December 31, 2015, the Presque Isle Power Plant shall meet the

Plant-specific 12-Month Rolling Tonnage for SO2 of 17,257 tons. (Civil Action No. 03-C-0371 Paragraph 174)

PM Emission Reduction and Controls Optimization of PM Controls: 1. The permittee shall continuously operate each Particulate Matter Control Device on its Existing Units to

maximize PM emission reductions, consistent with the operational and maintenance limitations of the Units. Specifically, the permittee shall, at a minimum: (Civil Action No. 03-C-0371 Paragraph 88) a. energize each section of the ESP for each Unit, regardless of whether that action is needed to comply

with opacity limits;

b. maintain the energy or power levels delivered to the ESPs for each Unit to achieve the greatest possible removal of PM;

c. make best efforts to expeditiously repair and return to service transformer-rectifier sets when they fail; and

d. maintain an ongoing bag leak detection and replacement program to assure optimal operation of each BH.

Particulate Matter Installation and Operation:




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1. The permittee shall install, certify, and operate PM CEMS (COMS) on the following Units, stacks or common

stacks in accordance with the following schedule: (Civil Action No. 03-C-0371 Paragraph 96)

Unit Deadline to Commence Operation Location

Presque Isle Unit 1-4 April 1, 2006 Common outlet flue at stack1

Presque Isle Unit 5 April 1, 2006 Stack2

Presque Isle Unit 6 April 1, 2006 Stack3

Presque Isle Units 7-9 April 1, 2006 Common outlet duct of TOXECON

Continuous opacity monitoring systems (COMS) are used on Presque Isle Units 5 and 6, and the output used as an indirect measurement of particulate matter. 1 Consent Decree paragraph 97 allows the permittee the choice of either installing two mercury CEMS, one at its

Pleasant Prairie Power Plant and another at its Oak Creek Power Plant (both part of the Wisconsin Electric System) in lieu of a PM CEMS on the common outlet flue of Presque Isle Units 1-4. The permittee has elected to install the two mercury monitors, and therefore no PM CEMS are located on Units 1-4. (Units 1 & 2 were retired on January 1, 2007 and Units 3 & 4 were retired on October 1, 2009) 2 In accordance with a proposal by the permittee to the U.S. Environmental Protection Agency on July 22, 2005,

and subsequent approval by the agency on September 28, 2005, the permittee is allowed to utilize existing COMS as an indirect measurement of particulate matter through a correlation curve developed by previous emission testing. 3 Same as described for Unit 5, the existing COMS on Unit 6 are used as an indirect measurement of particulate

matter through a correlation curve developed by previous emission testing.

PM Monitoring (For systems noted above) 1. The permittee shall undertake a program to install and operate Continuous Emission Monitoring System for

Particulate Matter (PM CEMS). Each PM CEMS (COMS) shall be comprised of a continuous particle mass monitor measuring particulate matter concentration, directly or indirectly, on an hourly average basis and a diluent monitor used to convert results to units of lb/MMBTU. The permittee shall maintain, in an electronic database, the hourly average emission values of all PM CEMS (COMS) in lb/MMBTU. The permittee shall use reasonable efforts to keep each PM CEMS running and producing data whenever any Unit served by the PM CEMS is operating. (Civil Action No. 03-C-0371 Paragraph 94)

2. The permittee shall submit to EPA for review and approval a plan for the installation and certification of each

PM CEMS (COMS) no later than one year prior to the deadline to commence operation. (Civil Action No. 03-C-0371 Paragraph 95)

3. Within 120 days prior to the deadline to operation of each PM CEMS (COMS), the permittee shall submit to

EPA for approval a proposed Quality Assurance/Quality Control (QA/QC) protocol that shall be followed in calibrating such PM CEMS (COMS). Following EPA’s approval of the protocol, the permittee shall operate each PM CEMS in accordance with the approved protocol. (Civil Action No. 03-C-0371 Paragraph 98)

4. In developing both the plan for installation and certification of the PM CEMS (COMS) and the QA/QC

protocol, the permittee may use the criteria set forth in EPA’s proposed revisions to Performance Specification 11: Specification and Test Procedures for PM CEMS and Procedure 2: PM CEMS at Stationary Sources (PS 11), as promulgated at 69 Fed. Reg. 1786, January 12, 2004, or other available PM CEMS (COMS) guidance. (Civil Action No. 03-C-0371 Paragraph 99)

5. No later than 90 days after the permittee begins operation of the PM CEMS, the permittee shall conduct tests

of each PM CEMS to demonstrate compliance with the PM CEMS plan submitted to and approved by EPA. (Civil Action No. 03-C-0371 Paragraph 100)

6. If after the permittee operates the PM CEMS for at least two years, and if the Parties then agree that it is

infeasible to continue operating PM CEMS, the permittee shall submit an alternative PM monitoring plan for review and approval by EPA. The plan shall include an explanation of the basis for stopping operation of the




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PM CEMS and a proposal for an alternative monitoring protocol. Until EPA approves such plan, the permittee shall continue to operate the PM CEMS. (Civil Action No. 03-C-0371 Paragraph 101)

7. Operation of a PM CEMS shall be considered “infeasible” if

a. the PM CEMS cannot be kept in proper condition for sufficient periods of time to produce reliable, adequate, or useful data consistent with the QA/QC protocol; or

b. the permittee demonstrates that recurring, chronic, or unusual equipment adjustment or servicing needs in relation to other types of continuous emission monitors cannot be resolved through reasonable expenditures of resources.

If the United States determines that the permittee has demonstrated infeasibility, the permittee shall be entitled to discontinue operation of and remove the PM CEMS. (Civil Action No. 03-C-0371 Paragraph 102)

PM Reporting 1. Following the installation of each PM CEMS, the permittee shall report to EPA data recorded by the PM

CEMS, expressed in lb/MMBTU on a 3-hour, 24-hour, 30-day, and 365-day rolling average basis in electronic format. (Civil Action No. 03-C-0371 Paragraph 103)

General PM Provisions 1. Particulate emissions may not exceed 0.030 pounds of filterable particulate matter emissions per million BTU,

excluding back-half, except during periods of startup and shutdown or during periods of control equipment or unit malfunction, if the malfunction meets the requirements of the force majeure section of the Consent Decree. Periods of startup shall not exceed two hours after any amount of coal is combusted. Periods of shutdown shall only commence when the unit ceases burning any amount of coal. (Civil Action No. 03-C-0371 Paragraphs 89 and 93)

2. The permittee shall use the reference methods specified in 40 CFR Part 60, Appendix A, Method 5 or Method

17, using stack tests, or alternative methods that are either promulgated by EPA or requested by the permittee and approved by EPA to determine the PM Emission Rate. The permittee shall also calculate the PM Emission Rates from annual (or biennial) stack tests in accordance with 40 CFR §60.8(f). The permittee shall also determine PM Emission Rates using PM CEMS consistent with the approved QA/QC protocol. (Civil Action No. 03-C-0371 Paragraph 104)

3. The permittee shall use data from the PM CEMS, at a minimum, to monitor progress in reducing PM

emissions. The Consent Decree is not intended to alter or waive any applicable law (including any defenses, entitlements, challenges, or clarifications related to the Credible Evidence Rule, 62 Fed. Reg. 8315 (Feb. 27, 1997)) concerning the use of data for any purpose under the Act, generated either by the reference methods specified herein or otherwise. (Civil Action No. 03-C-0371 Paragraph 105)

Prohibition on Netting Credits or Offsets from Required Controls 1. For any and all actions taken by the permittee to comply with the requirements of the Consent Decree,

including but not limited to the upgrade of ESPs and BHs, the installation of FGDs, SCRs, or equivalent control devices approved under this Consent Decree, the re-powering of certain units, the retirement of certain units, and the reduction of emissions to satisfy annual emission tonnage limitations, any emission reductions generated shall not be considered as a creditable contemporaneous emission decrease for the purpose of obtaining a netting credit under the Clean Air Act’s Non-attainment NSR and PSD programs. However, the permittee may use any creditable contemporaneous emission decreases of Volatile Organic Compounds (VOCs) generated under the Consent Decree for the purpose of obtaining a netting credit for VOCs under the Clean Air Act Non-attainment NSR and PSD programs. Nothing in the Consent Decree is intended to preclude the emission reductions generated under this Decree from being considered by the State of Michigan and EPA as creditable contemporaneous emission decreases for the purpose of attainment demonstrations submitted pursuant to § 110 of the Act, 42 U.S.C. § 7410, or in determining impacts on NAAQS and PSD increment consumption. (Civil Action No. 03-C-0371 Paragraph 106)




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D. Environmental Projects 1. The permittee shall design, construct, operate and analyze a full scale TOXECON with activated carbon

injection with the goal of achieving 90% mercury removal from Units 7, 8 and 9 flue gas emissions during the TOXECON project. (Civil Action No. 03-C-0371 Paragraph 108)

2. At least six months before operation of the TOXECON Project, the permittee shall submit an implementation

plan to the Plaintiffs for review and approval. The plan will include the date to commence design and construction of the Project as well as the date by which the Permittee will complete the TOXECON project. The plaintiffs to the consent decree shall be notified of any changes within 60 days of becoming aware a change is necessary. (Civil Action No. 03-C-0371 Paragraph 109)

3. Within 60 days of completion of the TOXECON project, the permittee shall submit to the EPA and MDEQ a

report that documents project completion date, results of implementation including emission reductions or other environmental benefits and permittee’s project cost. (Civil Action No. 03-C-0371 Paragraph 114)

4. The permittee shall, following completion of the TOXECON Project, maintain the baghouse component in the

flue gas stream regardless of demonstration results. If the permittee determines that the project demonstrates reasonable levels of mercury removal and operational viability, the permittee shall continue sorbent injection for mercury control. (Civil Action No. 03-C-0371 Paragraph 115)

5. The permittee shall provide to the United States and the MDEQ semi-annual updates of the TOXECON project

progress. This information shall also be made available to the public according to paragraph 179 of the Consent Decree. Information disclosure shall include periodic progress reports that identify demonstrated removal efficiencies of mercury and other pollutants, sorbent injection rates and cost effectiveness. Per limitations described in paragraph 179 of the Consent Decree, periodic technology transfer open houses and plant tours shall be scheduled according to DOE requirements for project information disclosure. (Civil Action No. 03-C-0371 Paragraph 117)




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C. EMISSION UNIT CONDITIONS

Part C outlines terms and conditions that are specific to individual emission units listed in the Emission Unit Summary Table. The permittee is subject to the special conditions for each emission unit in addition to the General Conditions in Part A and any other terms and conditions contained in this ROP. The permittee shall comply with all specific details in the special conditions and the underlying applicable requirements cited. If a specific condition type does not apply, NA (not applicable) has been used in the table. If there are no conditions specific to individual emission units, this section will be left blank.

EMISSION UNIT SUMMARY TABLE The descriptions provided below are for informational purposes and do not constitute enforceable conditions.

Emission Unit ID Emission Unit Description

(Including Process Equipment & Control Device(s))

Installation Date/

Modification Date

Flexible Group ID

EUBOILER5

Boiler #5 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 995 MMBTU/hr. The boiler serves a GE steam turbine/ generator set rated at 78,973 KW. Bottom ash from this boiler is permitted to be re-burned in Boilers #7, #8, and #9 under Permit #299-01A. Boiler #5 was modified in 2002 with the addition of low-NOx burners under Air Use Permit #299-01. Included in this emission unit are an electrostatic precipitator and fabric filter baghouse. The new baghouse was installed in 2005 in series with the ESP. {Permits to Install #856-87B, #299-01, #299-01A}

1974 2002 2005

NA




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Installation Date/

Modification Date

Flexible Group ID

EUBOILER6

Boiler #6 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 995 MMBTU/hr. The boiler serves a GE steam turbine/generator set rated at 78,973 KW. Bottom ash from this boiler is permitted to be re-burned in Boilers #7, #8, and #9 under Permit #299-01A. Boiler #6 was modified in 2002 with the addition of low-NOx burners under Air Use Permit #299-01. Included in this emission unit are an electrostatic precipitator and fabric filter baghouse. The new baghouse was installed in 2005 in series with the ESP. {Permits to Install #856-87B, #299-01, #299-01A}

1975 2002 2005

NA

EUBOILER7

Boiler #7 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 1010 MMBTU/hr. The boiler serves a GE steam turbine/generator set rated at 78,982 KW. Bottom ash from Boilers #5 and #6 is permitted to be re-burned in this boiler under Permit #299-01A. Mercury emissions from Boilers #7, #8, and #9 are controlled with a TOXECON

TM mercury

control demonstration system installed in 2005. Included in this emission unit are an electrostatic precipitator and the TOXECON

TM fabric filter baghouse common

to Boilers #7 through #9. {Permits to Install #856-87B and #299-01A}

1978 2005

NA




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Installation Date/

Modification Date

Flexible Group ID

EUBOILER8


TM mercury




1978 2005

NA

EUBOILER9


TM mercury




1979 2005

NA

EUASHHANDLING

Various ash handling processes throughout the plant complex, including flyash unloaders, flyash transfer from electrostatic precipitator and baghouse hoppers to day silos, and to storage silos for off-season storage of flyash. Flyash transfer operations and storage silos are controlled with concentric loading/venting systems and/or baghouse dust collectors. Ash disposal methods incorporate dust control measures and work practices as specified in the Fugitive Dust Minimization Plan.

NA NA




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Installation Date/

Modification Date

Flexible Group ID

EUMATERIALHANDLING

Various material handling processes throughout the plant complex, including the Ship Unloading Facility, outdoor fuel storage pile, limestone handling, plant yard and roadways, radial arm stacker, and coal transfer into the power plant boilers’ coal bunkers. Dust control measures include cyclonic and fabric filter dust collectors, sweeping, flushing, water sprays, dust suppressants, enclosures, barriers, and work practices as specified in the Fugitive Dust Minimization Plan.

NA NA

EUICDIESEL1 Unit 5-6 Emergency Generator, Diesel fired, 380 BHP, less than 10 MMBTU/hr

1971 FGICDIESELS

EUICDIESEL2 Unit 7-9 Emergency Generator, Diesel fired, 710 BHP, less than 10 MMBTU/hr

1971 NA

EUICDIESEL3 Emergency Fire Pump, Diesel fired, 170 BHP, less than 10 MMBTU/hr

1971 FGICDIESELS




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EUBOILER5 EMISSION UNIT CONDITIONS

DESCRIPTION Boiler #5 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 995 MMBTU/hr. The boiler serves a GE steam turbine/ generator set rated at 78,973 KW. Flexible Group ID: NA POLLUTION CONTROL EQUIPMENT Low NOx Burners, Electrostatic Precipitator, Fabric Filter Baghouse I. EMISSION LIMITS

Pollutant Limit Time

Period/ Operating Scenario

Equipment Monitoring/

Testing Method

Underlying Applicable

Requirements

1. Particulate Matter (PM)

a. 0.20 lb / 1000 lbs of exhaust gases, corrected to 50% excess air

2

b. 0.030 lb of filterable PM

per MMBTU excluding back-half

a. Test Protocol b. Test Protocol

EUBOILER5

Section V, Section VII.8

a. R 336.1331 R336.1201(3)

b. Civil Action No. 03-C-0371 Paragraph 89

2. Sulfur dioxide (SO2)

1.67 pounds / MMBTU heat input

2

24-Hour Period

EUBOILER5 Section VI.15 R 336.1401 R336.1201(3)

II. MATERIAL LIMITS 1. The maximum sulfur content in the coal shall not exceed 1.0 percent by weight. The permittee shall maintain

records of emissions and operating information including SO2 emissions or sulfur content of the fuel, rate of fuel burned, heating value, ash content, average electrical output, and minimum and maximum hourly generation rate. See Appendix 4.

2 (R336.1201(3)), (R 336.1401)

2. The permittee shall not burn coal in EUBOILER5 having a sulfur content greater than any amount authorized

by regulation or state permit and shall not receive petroleum coke at any Unit that is not controlled by a Flue Gas Desulfurization System (FGD) or equivalent SO2 technology. (Civil Action No. 03-C-0371 Paragraph 85)




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III. PROCESS/OPERATIONAL RESTRICTIONS 1. The permittee shall not operate EUBOILER5 unless the associated electrostatic precipitator (ESP) is

operating properly.2 (R 336.1201(3))

2. The permittee shall use either low NOx burners (LNB) or combustion control technology when operating

EUBOILER5. (Civil Action No. 03-C-0371 Paragraph 61)

IV. DESIGN/EQUIPMENT PARAMETERS 1. NA

V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. Within three years of the effective date of this permit, the permittee shall conduct PM testing of EUBOILER5

to determine compliance with the emission limit specified in Special Condition 1.1a. The permittee shall submit a complete test protocol to the AQD for approval at least 30 days prior to the anticipated test date. The permittee shall notify the AQD no less than 7 days prior to the anticipate test date. The permittee shall submit two complete test reports of the test results to the AQD, one to the Technical Program Unit and one to the district office, within 60 days following the last date of the test. (R 336.1213(3)), R336.2001(3), R336.2001(4)

2. The permittee shall conduct an annual PM stack test on SVFLUE5 to show compliance with the PM emission

limit specified in Special Condition I.1b. The annual stack test requirement may be satisfied by the permittee’s stack tests required in the year as stated in Special Condition V.1. The permittee may perform biennial rather than annual testing provided that one of the following are met: (Civil Action No. 03-C-0371 Paragraph 91) a. Two of the most recently completed test results conducted in accordance with Method 5 or Method 17

demonstrate that the PM emissions are equal to or less than 0.015 lb/MMBTU; or

b. EUBOILER5 is equipped with a PM CEMS (COMS).

The permittee shall perform annual rather than biennial testing the year immediately following any test result demonstrating that the PM emissions are greater than 0.015 lb/MMBTU.

VI. MONITORING/RECORDKEEPING

Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. The permittee shall measure the pressure drop across the baghouse and take continuous readings as an

indicator of proper operation of the baghouse. The indicator range shall be as specified in the most recent CAM Plan and based on a 3-hr block average, excluding those events defined as startup, shutdown or malfunction. (40 CFR 64.6(c)(1)(i and ii))

2. The permittee shall utilize COM-recorded opacity as an additional indicator of the proper operation of the

baghouse. The indicator range of opacity defining proper function of the baghouse is less than 15 percent opacity based on a 3-hr block average. (40 CFR 64.6(c)(1)(i and ii))

3. The permittee shall conduct all required monitoring per the CAM Plan and otherwise satisfy the requirements

specified in 40 CFR 64.7 through 40 CFR 64.9. (40 CFR 64.6(c)(3), 40 CFR 64.7(a))

4. For each control device in operation, the permittee shall conduct bypass monitoring for each bypass line such that the valve or closure method cannot be opened without creating an alarm condition for which a record shall be made. Records of the bypass line that was opened and the length of time the bypass line was opened shall be kept on file. (40 CFR 64.3(a)(2))




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5. The opacity monitor and pressure gauge shall continuously monitor the opacity and the pressure drop across the baghouse. The averaging period is a 3-hour block average. The opacity monitor shall be properly maintained and calibrated, with daily periodic cleaning of optical surfaces. For the pressure drop monitor, the pressure taps and the transmitter shall be inspected and calibrated during major outages. (40 CFR 64.6(c)(1)(iii))

6. An excursion is a departure from the indicator range specified in the most recent CAM Plan for pressure

gauge readings based on a 3-hour block average or above 15% opacity based on a 3-hour block average for the opacity monitor. (40 CFR 64.6(c)(2))

7. The permittee shall operate the COMS during all required periods when the coal-fired boiler is operating.

Data recorded during monitoring malfunctions, repair activities, startup and shutdown (SU/SD) periods and QA/QC operations shall not be used for 40 CFR Part 64 compliance. (40 CFR 64.6(c)(3), 64.7(c))

8. Upon detecting an excursion or exceedance, the owner or operator shall restore operation of the pollutant-

specific emissions unit (including the control device and associated capture system) to its normal or usual manner of operation as expeditiously as practicable in accordance with good air pollution control practices for minimizing emissions. The response shall include minimizing the period of any startup, shutdown or malfunction and taking any necessary corrective actions to restore normal operation and prevent the likely recurrence of the cause of an excursion or exceedance (other than those caused by excused startup or shutdown conditions). (40 CFR 64.7(d))

9. Except for, as applicable, monitoring malfunctions, associated repairs, and required quality assurance or

control activities (including, as applicable, calibration checks and required zero and span adjustments), the owner or operator shall conduct all monitoring in continuous operation (or shall collect data at all required intervals) at all times that the pollutant-specific emissions unit is operating. Data recorded during monitoring malfunctions, associated repairs, and required quality assurance or control activities shall not be used for purposes of this part, including data averages and calculations or fulfilling a minimum data availability requirement, if applicable. The owner or operator shall use all the data collected during all other periods in assessing the operation of the control device and associated control system. A monitoring malfunction is any sudden, infrequent, not reasonably preventable failure of the monitoring to provide valid data. Monitoring failures that are caused in part by poor maintenance or careless operation are not malfunctions. (40 CFR 64.6(c)(3), 64.7(c))

10. The permittee shall properly maintain the monitoring systems, including keeping necessary parts for routine

repair of the monitoring equipment. (40 CFR 64.7(b))

OPACITY MONITORING 11. The permittee shall calibrate, monitor, and record visible emissions on a continuous basis, with certified

instrumentation, and in a manner acceptable to the Air Quality Division.2 (R 336.1201(3), R 336.2101,

R 336.2170) 12. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions

report (EER).2 (R 336.1201(3), R 336.2101, R 336.2170)

13. The permittee shall perform an annual audit of the COMS, and shall submit a copy of it to the Air Quality

Division within 30 days following the end of the calendar quarter in which the audit was conducted.2

(R 336.1201(3), R 336.2101, USEPA Publication 450/4-92-010 Performance Audit Procedures for Opacity Monitors)

14. The permittee shall use the output from the COMS to correlate the PM emissions from EUBOILER5. (Civil

Action No. 03-C-0371 Paragraph 96 pursuant to Part B. Source-Wide Conditions, Particulate Matter, Condition 1, footnote 2 in table)




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GASEOUS EMISSIONS MONITORING 15. The permittee shall calibrate, monitor, and record SO2 and NOx emissions on a continuous basis, with

certified instrumentation, and in a manner acceptable to the Air Quality Division.2 (R 336.1201(3), 40 CFR

Part 75, R 336.1801)

16. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions report (EER) and summary report for SO2.

2 (R 336.1201(3), 40 CFR 60.7 (c) and (d), 40 CFR Part 75)

17. The permittee shall perform and report Quality Assurance Procedures of the CEMS and submit it to the Air

Quality Division in a format of the data assessment report (DAR) along with the quarterly EER and summary reports.

2 (R 336.1201(3), 40 CFR Part 60 Appendices B and F, 40 CFR Part 75)

VII. REPORTING

1. Prompt reporting of deviations pursuant to General Conditions 21 and 22 of Part A. See Appendix 8.

(R 336.1213(3)(c)(ii)) 2. Semiannual reporting of monitoring and deviations pursuant to General Condition 23 of Part A. See Appendix

8. Report shall be postmarked or received by appropriate AQD district office by March 15 for reporting period July 1 to December 31 and September 15 for reporting period January 1 to June 30. (R 336.1213(3)(c)(i))

3. Annual certification of compliance pursuant to General Conditions 19 and 20 of Part A. See Appendix 8.

Report shall be postmarked or received by appropriate AQD district office by March 15 for the previous calendar year. (R 336.1213(4)(c))

4. If required in accordance with the CAM Plan, each semiannual report of monitoring and deviations shall

include a description of the actions taken to implement a QIP during the reporting period. If a QIP has been completed, the report shall include documentation that the plan has been implemented and if it has reduced the likelihood of excursions or exceedances. (40 CFR 64.9(a)(2)(iii))

5. Each semiannual report of monitoring and deviations shall include summary information on the number,

duration and cause of excursions and/or exceedances and the corrective actions taken. If there were no excursions and/or exceedances in the reporting period, then this report shall include a statement that there were no excursions and/or exceedances. (40 CFR 64.9(a)(2)(i))

6. Each semiannual report of monitoring and deviations shall include summary information on monitor downtime.

If there were no periods of monitor downtime in the reporting period, then this report shall include a statement that there were no periods of monitor downtime. (40 CFR 64.9(a)(2)(ii))

7. The reference and monitoring methods and procedures for determining compliance with the emission limits

for PM shall be those specified in 40 CFR Part 60, Appendix A, Method 5 or Method 17. Use of any particular method shall conform to the EPA requirements specified in 40 CFR Part 60, Appendix A and 40 CFR 60.48a (b) and (e), or federally approved SIP method. The permittee shall calculate the PM emission rates from the stack test results in accordance with 40 CFR 60.8(f) and 40 CFR 60.46a (c). The results of each PM stack test shall be submitted to the EPA and the MDEQ within 45 days of the completion of each test. (Civil Action No. 03-C-0371 Paragraph 92)

See Appendix 8 VIII. STACK/VENT RESTRICTIONS

The exhaust gases from the stacks listed in the table below shall be discharged unobstructed vertically upwards to the ambient air unless otherwise noted:




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Stack & Vent ID Maximum Exhaust Dimensions (inches)

Minimum Height Above

Ground (feet)

Underlying Applicable Requirements

SVFLUE5 1081 400

1 R 336.1201(3)

IX. OTHER REQUIREMENTS 1. The permittee shall comply with all applicable requirements of 40 CFR Part 64 and implement the submitted

Compliance Assurance Monitoring (CAM) plan in conformance with 40 CFR Part 64 to ensure compliance with the emission limits for particulate matter. (40 CFR Part 64)

2. The permittee shall promptly notify the AQD if a modification to the CAM Plan is needed because the existing

plan is found to be inadequate and shall submit a proposed modification to the ROP if necessary. (40 CFR 64.7(e))

3. The permittee shall submit a QIP if 10 excursions occur in any 6 month period. (40 CFR 64.8(a)) PHASE II ACID RAIN PERMIT

4. The permittee shall comply with the acid rain permitting provisions of 40 CFR 72.1 to 72.94 as outlined in a

complete Phase II Acid Rain Permit issued by the Air Quality Division. Phase II Acid Rain Permit No. MI-AR-1769-20XX is hereby incorporated into this Renewable Operating Permit as Appendix 9. (R 336.1299(d))

5. The permittee shall not allow the emission of an air pollutant to exceed the amount of any emission

allowances that an affected source lawfully holds as of the allowance transfer deadline pursuant to R 336.1299(d) and 40 CFR 72.9(c)(1)(i). (R 336.1213(10))

6. The permittee shall comply with the CAIR SO2 Trading Program provisions of 40 CFR Part 96.201 through

96.288, as adopted and modified by R 336.1420, and as outlined in any complete CAIR SO2 permit issued by the AQD. CAIR SO2 Permit No. MI-SO2-1769-20XX is hereby incorporated into this ROP as Appendix 10. (R 336.1420)

7. The permittee shall hold allowances for compliance deductions in the source’s compliance account as of the

allowance transfer deadline in an amount not less than the total SO2 emissions for the control period from the source pursuant to 40 CFR Part 96.254. (40 CFR Part 96.254)

8. The permittee shall comply with the CAIR NOx Annual Trading Program provisions of 40 CFR Part 96.101

through 96.188, as adopted and modified by R 336.1802a, 336.1803, 336.1821, and 336.1830 through 336.1834, and as outlined in any complete CAIR NOx Annual permit issued by the AQD. CAIR NOx Annual Permit No. MI-NOA-1769-20XX is hereby incorporated into this ROP as Appendix 11. (R 336.1821)


allowance transfer deadline in an amount not less than the total NOx emissions for the control period from the source pursuant to 40 CFR Part 96.154. (40 CFR Part 96.154)

10. The permittee shall comply with the CAIR NOx Ozone Trading Program provisions of 40 CFR Part 96.301

through 96.388, as adopted and modified by R 336.1802a, 336.1803, and 336.1821 through 336.1826, and as outlined in any complete CAIR NOx Annual permit issued by the AQD. CAIR NOx Ozone Permit No. MI-NOO-1769-20XX is hereby incorporated into this ROP as Appendix 12. (R 336.1821)






Page 27 of 93

12. Effective January 1, 2015, an affected existing EGU shall meet the requirements of Part 15 Emission Limitations and Prohibitions – Mercury. (R 336.2503(1))

13. Upon promulgation, an affected existing EGU shall meet the requirements of 40 CFR 63, Subpart UUUUU-

National Emission Standards for Hazardous Air Pollutants: Coal- and Oil-fired Electric Utility Steam Generating Units. (40 CFR 63.9981, 40 CFR 63.9982)

14. Permittee shall implement and maintain an approved Malfunction Abatement Plan for the Fabric Filter

Baghouse Dust Collection System and the Electrostatic Precipitator PM Control System. (R336.1911) Footnotes: 1This condition is state only enforceable and was established pursuant to Rule 201(1)(b).





Page 28 of 93


DESCRIPTION Boiler #6 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 995 MMBTU/hr. The boiler serves a GE steam turbine/generator set rated at 78,973 KW. Flexible Group ID: NA POLLUTION CONTROL EQUIPMENT Low NOx Burners, Electrostatic Precipitator, Fabric Filter Baghouse I. EMISSION LIMITS

Pollutant Limit Time Period/

Operating Scenario


Testing Method


Requirements 1. Particulate

Matter (PM)

a. 0.20 lb / 1000 lbs of exhaust gases, corrected to 50% excess air

2



a. Test Protocol b. Test Protocol

EUBOILER6

Section V Section VII.8

a. R 336.1331 R336.1201(3)

b. Civil Action No. 03-C-0371 Paragraph 89

2. Sulfur Dioxide (SO2)

1.67 lbs / MMBTU heat input

2

24-Hour Period

EUBOILER6 Section VI.15 R 336.1401 R336.1201(3))

II. MATERIAL LIMITS 1. The maximum sulfur content in the coal shall not exceed 1.0 percent by weight. The permittee shall maintain

records of emissions and operating information including SO2 emissions or sulfur content of the fuel, rate of fuel burned, heating value, ash content, average electrical output, and minimum and maximum hourly generation rate. See Appendix 42

. (R336.1201(3)), (R 336.1401) 2. The permittee shall not burn coal in EUBOILER6 having a sulfur content greater than any amount authorized









Page 29 of 93



to determine compliance with the emission limit specified in Special Condition I.1a. The permittee shall submit a complete test protocol to the AQD for approval at least 30 days prior to the anticipated test date. The permittee shall notify the AQD no less than 7 days prior to the anticipate test date. The permittee shall submit two complete test reports of the test results to the AQD, one to the Technical Program Unit and one to the district office, within 60 days following the last date of the test. (R 336.1213(3)), R336.2001(3), R336.2001(4)




b. EUBOILER6 is equipped with a PM CEMS (COMS).


VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. The permittee shall measure the pressure drop across the baghouse and take continuous readings as an


2. The permittee shall utilize COM-recorded opacity as an additional indicator of the proper operation of the

baghouse. The indicator range of opacity defining proper function of the baghouse is less than 15 percent opacity based on a 3-hr block average. (40 CFR 64.6(c)(1)(i and ii))


specified in 40 CFR 64.7 through 40 CFR 64.9. (40 CFR 64.6(c)(3), 40 CFR 64.7(a)) 4. For each control device in operation, the permittee shall conduct bypass monitoring for each bypass line such

that the valve or closure method cannot be opened without creating an alarm condition for which a record shall be made. Records of the bypass line that was opened and the length of time the bypass line was opened shall be kept on file. (40 CFR 64.3(a)(2))

5. The opacity monitor and pressure gauge shall continuously monitor the opacity and the pressure drop across

the baghouse. The averaging period is a 3-hour block average. The opacity monitor shall be properly maintained and calibrated daily with periodic cleaning of optical surfaces. For the pressure drop monitor, the pressure taps and the transmitter shall be inspected and calibrated during major outages. (40 CFR 64.6(c)(1)(iii)

6. An excursion is a departure from the indicator range specified in the most recent CAM Plan for pressure





Page 30 of 93


Data recorded during monitoring malfunctions, repair activities, startup and shutdown (SU/SD) periods and QA/QC operations shall not be used for 40 CFR Part 64 compliance. (40 CFR 64.6(c)(3), 64.7(c))






repair of the monitoring equipment. (40 CFR 64.7(b)) OPACITY MONITORING

11. The permittee shall calibrate, monitor, and record visible emissions on a continuous basis, with certified

instrumentation, and in a manner acceptable to the Air Quality Division.2 (R 336.1201(3), R 336.2101,

R 336.2170) 12. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions

report (EER).2 (R 336.1201(3), R 336.2101, R 336.2170)



(R 336.1201(3), R 336.2101, USEPA Publication 450/4-92-010 Performance Audit Procedures for Opacity Monitors)

14. The permittee shall use the output from the COMS to correlate the PM emissions from EUBOILER6.

(Civil Action No. 03-C-0371 Paragraph 96 pursuant to Part B. Source-Wide Conditions, Particulate Matter, Condition 1, footnote 3 in table)



Part 75, R 336.1801)

16. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions report (EER) and summary report for SO2.

2 (R 336.1201(3), 40 CFR 60.7 (c) and (d), 40 CFR Part 75)




Page 31 of 93

17. The permittee shall perform and report Quality Assurance Procedures of the CEMS and submit it to the Air Quality Division in a format of the data assessment report (DAR) along with the quarterly EER and summary reports.

2 (R 336.1201(3), 40 CFR Part 60 Appendices B and F, 40 CFR Part 75)

VII. REPORTING
















Stack & Vent ID Maximum Exhaust

Dimensions (inches)


Ground (feet)


SVFLUE6 1081 400

1 R 336.1201(3)

IX. OTHER REQUIREMENTS

1. The permittee shall comply with all applicable requirements of 40 CFR Part 64 and implement the submitted





Page 32 of 93



3. The permittee shall submit a QIP if 10 excursions occur in any 6 month period. (40 CFR 64.8(a)) PHASE II ACID RAIN PERMIT 4. The permittee shall comply with the acid rain permitting provisions of 40 CFR 72.1 to 72.94 as outlined in a


5. The permittee shall not allow the emission of an air pollutant to exceed the amount of any emission allowances that an affected source lawfully holds as of the allowance transfer deadline pursuant to R 336.1299(d) and 40 CFR 72.9(c)(1)(i). (R 336.1213(10))



7. The permittee shall hold allowances for compliance deductions in the source’s compliance account as of the allowance transfer deadline in an amount not less than the total SO2 emissions for the control period from the source pursuant to 40 CFR Part 96.254. (40 CFR Part 96.254)









12. Effective January 1, 2015, an affected existing EGU shall meet the requirements of Part 15 Emission

Limitations and Prohibitions – Mercury. (R 336.2503(1)) 13. Upon promulgation, an affected existing EGU shall meet the requirements of 40 CFR 63, Subpart UUUUU-








Page 33 of 93


DESCRIPTION Boiler #7 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 1010 MMBTU/hr. The boiler serves a GE steam turbine/generator set rated at 78,982 KW. Bottom ash from Boilers #5 and #6 is permitted to be re-burned in this boiler. Flexible Group ID: NA

POLLUTION CONTROL EQUIPMENT TOXECON

TM Mercury Control, Electrostatic Precipitator, TOXECONTM Fabric Filter Baghouse

I. EMISSION LIMITS


Operating Scenario

Equipment Monitoring/ Testing Method


Requirements 1. Nitrogen

Oxides (NOx)

a. 0.70 lbs/MMBTU heat input

2

3-Hour Average EUBOILER7

Section VI.15, 19, Performance test established by 40

CFR 60.8

40 CFR Part 60 Subparts A & D


a. 0.10 lb / MMBTU heat input

2 b. 0.030 lb of

filterable PM per MMBTU excluding back-half

a. Test Protocol

b. Test Protocol

EUBOILER7 Section V, Section VII.8

a. R 336.1331 40 CFR Part 60 Subparts A & D R336.1201(3)) b. Civil Action No. 03-C-0371 Paragraph 89

3. Sulfur Oxides (SOx)


2

3-Hour Average

EUBOILER7 Section VI. 15, 19 Performance test

established by 40 CFR 60.8

40 CFR Part 60 Subparts A & D R336.1201(3))

4. Visible Emissions

20% opacity, except as specified in 40 CFR

Part 60 Subparts A & D

2

Test Protocol EUBOILER7 Section VI.7,12

R 336.1301, R336.1201(3)


II. MATERIAL LIMITS 1. The permittee shall not reburn in EUBOILER7 more than 2520 tons per calendar month of bottom ash from

Boilers #5 through #6.2 (R 336.1201(3))






Page 34 of 93



2. Diversion from the TOXECON baghouse during routine or scheduled maintenance as referenced in the

Malfunction Abatement Plan shall not be a reportable deviation of the requirement to properly operate the air pollution control devices. (R336.1213(3))









b. EUBOILER7 is equipped with a PM CEMS on the common duct of the TOXECON baghouse connecting with EUBOILER8 and EUBOILER9.




2. The permittee shall utilize COM-recorded opacity as an indicator of the proper operation of the electrostatic

precipitator when diversion occurs as identified in Special Condition III.2. The indicator range of opacity defining proper function of the ESP is 18 percent based on a 3-hr block average. (40 CFR 64.6(c)(1)(i and ii))





Page 35 of 93


the baghouse. The averaging period is a 3-hour block average. The opacity monitor shall be properly maintained and calibrated daily with periodic cleaning of optical surfaces. For the pressure drop monitor, the pressure taps and the transmitter shall be inspected and calibrated during major outages. (40 CFR 64.6(c)(1)(iii))


specified in 40 CFR 64.7 through 40 CFR 64.9. (40 CFR 64.6(c)(3), 40 CFR 64.7(a)) 6. An excursion is a departure from the indicator range specified in the most recent CAM Plan for pressure



Data recorded during monitoring malfunctions, repair activities, startup and shutdown operations, and QA/QC operations shall not be used for 40 CFR Part 64 compliance. (40 CFR 64.6(c)(3), 64.7(c))






repair of the monitoring equipment. (40 CFR 64.7(b)) OPACITY MONITORING 12. The permittee shall calibrate, monitor, and record visible emissions on a continuous basis, with certified

instrumentation, and in a manner acceptable to the Air Quality Division.2 (R 336.1201(3), 40 CFR 60.13, 40

CFR Part 60 Appendix B Performance Specification 1) 13. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions

report (EER).2 (R 336.1201(3), 40 CFR 60.7 (c) and (d))



(R 336.1201(3), USEPA Publication 450/4-92-010 Performance Audit Procedures for Opacity Monitors)




Page 36 of 93



60.13, 40 CFR Part 60 Appendix B Performance Specification 2, 40 CFR Part 75, R 336.1801) 16. For the three-hour average SO2 and NOx emission limits specified under EMISSION LIMITS above, excess

emissions are defined as any three-hour period during which the average emissions (arithmetic average of the three contiguous one-hour periods as measured by the continuous monitoring system) exceed the emission limit.

2 (R 336.1201(3), 40 CFR 60.45(g)(2) and (3))

17. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions

report (EER) for SO2 and NOx.2 (R3236.1201(3), 40 CFR 60.7(c) and (d), 40 CFR Part 75)



2 (R 336.1201(3), 40 CFR Part 60 Subparts A and D and Appendix F, 40 CFR Part 75)

OTHER MONITORING OR RECORDKEEPING 19. The permittee shall maintain records of emissions and operating information including NOx emissions, SO2

emissions or sulfur content of the fuel, rate of fuel burned, heating value, ash content, average electrical output, and minimum and maximum hourly generation rate. See Appendix 4.

2 (R336.1201(3)), (40 CFR Part 60 Subparts A and D, 40 CFR Part 75)

VII. REPORTING










6. Each semiannual report of monitoring and deviations shall include summary information on monitor downtime. If there were no periods of monitor downtime in the reporting period, then this report shall include a statement that there were no periods of monitor downtime. (40 CFR 64.9(a)(2)(ii))

7. The reference and monitoring methods and procedures for determining compliance with the emission limits for PM shall be those specified in 40 CFR Part 60, Appendix A, Method 5 or Method 17. Use of any particular method shall conform to the EPA requirements specified in 40 CFR Part 60, Appendix A and 40 CFR 60.48a (b) and (e), or federally approved SIP method. The permittee shall calculate the PM emission rates from the stack test results in accordance with 40 CFR 60.8(f) and 40 CFR 60.46a (c). The results of each PM stack




Page 37 of 93

test shall be submitted to the EPA and the MDEQ within 45 days of the completion of each test. (Civil Action No. 03-C-0371 Paragraph 92)



Stack & Vent ID

Maximum Exhaust Dimensions (inches)


Ground (feet)


1. SVFLUE7 1141 410

1 R 336.1201(3)


1. The permittee shall comply with all applicable requirements of 40 CFR Part 64 and implement the submitted Compliance Assurance Monitoring (CAM) plan in conformance with 40 CFR Part 64 to ensure compliance with the emission limits for particulate matter. (40 CFR Part 64)



3. The permittee shall submit a QIP if 10 excursions occur in any 6 month period. (40 CFR 64.8(a)) 4. As would apply to any other condition in this permit, nothing in this permit shall preclude the use, including

exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed.

2 (40 CFR 60.11(g))

PHASE II ACID RAIN PERMIT 5. The permittee shall comply with the acid rain permitting provisions of 40 CFR 72.1 to 72.94 as outlined in a



allowances that an affected source lawfully holds as of the allowance transfer deadline pursuant to R 336.1299(d) and 40 CFR 72.9(c)(1)(i). (R 336.1213(10))










Page 38 of 93









National Emission Standards for Hazardous Air Pollutants: Coal- and Oil-fired Electric Utility Steam Generating Units. 40 CFR 63.9981, 40 CFR 63.9982)







Page 39 of 93


DESCRIPTION Boiler #8 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 1010 MMBTU/hr. The boiler serves a GE steam turbine/generator set rated at 78,982 KW. Bottom ash from Boilers #5 and #6 is re-burned in this boiler. Flexible Group ID: NA POLLUTION CONTROL EQUIPMENT TOXECON

TM Mercury Control, Electrostatic Precipitator, TOXECONTM Fabric Filter Baghouse

I. EMISSION LIMITS


Operating Scenario

Equipment Monitoring/ Testing Method


Requirements 1. Nitrogen

Oxides (NOx)

1. 0.70 lb / MMBTU heat input

2

3-Hour Average EUBOILER8

Section VI. 15, 19, Performance test





2 b. 0.030 lb of

filterable PM per MMBTU excluding back-half

a. Test Protocol

b. Test Protocol

EUBOILER8 Section V, Section VII.8

a. R 336.1331 40 CFR Part 60 Subparts A & D

R336.1201(3) b. Civil Action No. 03-C-0371 Paragraph 89

3. Sulfur Oxides (SOx)


2

3-Hour Average

EUBOILER8 Section VI. 15, 19 Performance test


R336.1201(3) 40 CFR Part 60 Subparts A & D


20% opacity, except as specified in 40

CFR Part 60 Subparts A & D

2


R 336.1301, R336.1201(3)









Page 40 of 93















See Appendix 5








Page 41 of 93





specified in 40 CFR 64.7 through 40 CFR 64.9. (40 CFR 64.6(c)(3), 40 CFR 64.7(a)) 6. An excursion is a departure from the indicator range as specified in the most recent CAM Plan for pressure









repair of the monitoring equipment. (40 CFR 64.7(b)) OPACITY MONITORING 12. The permittee shall calibrate, monitor, and record visible emissions on a continuous basis, with certified

instrumentation, and in a manner acceptable to the Air Quality Division.2 (R 336.1201(3), 40 CFR 60.13,

40 CFR Part 60 Appendix B Performance Specification 1)

13. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions report (EER).

2 (R 336.1201(3), 40 CFR 60.7 (c) and (d))




Page 42 of 93

14. The permittee shall perform an annual audit of the COMS, and shall submit a copy of it to the Air Quality Division within 30 days following the end of the calendar quarter in which the audit was conducted.

2 (R 336.1201(3), USEPA Publication 450/4-92-010 Performance Audit Procedures for Opacity Monitors)



60.13, 40 CFR Part 60 Appendix B Performance Specification 2, 40 CFR Part 75, R 336.1801)

16. For the three-hour average SO2 and NOx emission limits specified under EMISSION LIMITS above, excess emissions are defined as any three-hour period during which the average emissions (arithmetic average of the three contiguous one-hour periods as measured by the continuous monitoring system) exceed the emission limit.

2 (R 336.1201(3), 40 CFR 60.45(g)(2) and (3))


report (EER) for SO2 and NOx.2 (R 336.1201(3), 40 CFR 60.7(c) and (d), 40 CFR Part 75)





emissions or sulfur content of the fuel, rate of fuel burned, heating value, ash content, average electrical output, and minimum and maximum hourly generation rate. See Appendix 4.

2 (R336.1201(3)), (40 CFR Part 60 Subparts A and D, 40 CFR Part 75)

VII. REPORTING















Page 43 of 93

7. The reference and monitoring methods and procedures for determining compliance with the emission limits for PM shall be those specified in 40 CFR Part 60, Appendix A, Method 5 or Method 17. Use of any particular method shall conform to the EPA requirements specified in 40 CFR Part 60, Appendix A and 40 CFR 60.48a (b) and (e), or federally approved SIP method. The permittee shall calculate the PM emission rates from the stack test results in accordance with 40 CFR 60.8(f) and 40 CFR 60.46a (c). The results of each PM stack test shall be submitted to the EPA and the MDEQ within 45 days of the completion of each test. (Civil Action No. 03-C-0371 Paragraph 92)




Dimensions (inches)


Ground (feet)


1. SVFLUE8 1141 410

1 R 336.1201(3)

IX. OTHER REQUIREMENTS 1. The permittee shall comply with all applicable requirements of 40 CFR Part 64 and implement the submitted





exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed.

2 (40 CFR 60.11(g))




allowances that an affected source lawfully holds as of the allowance transfer deadline pursuant to R 336.1299(d).and 40 CFR 72.9(c)(1)(i). (R 336.1213(10))








Page 44 of 93











National Emission Standards for Hazardous Air Pollutants: Coal-and Oil-fired Electric Utility Steam Generating Units. (40 CFR 63.9981, 40 CFR 63.9982)







Page 45 of 93


DESCRIPTION Boiler #9 is a Riley pulverized coal wall fired dry bottom utility boiler which uses distillate oil start-up guns and periodically evaporates and combusts non-hazardous boiler cleaning liquids concurrently with coal firing. Nameplate steam capacity rating is 615,000 lb/hr. The heat input capacity is approximately 1010 MMBTU/hr. The boiler serves a GE steam turbine/generator set rated at 78,982 KW. Bottom ash from Boilers #5 through #6 is re-burned in this boiler. Flexible Group ID: NA POLLUTION CONTROL EQUIPMENT TOXECON

TM mercury control demonstration system, electrostatic precipitator, TOXECON

TM fabric filter baghouse

I. EMISSION LIMITS

Pollutant Limit Time

Period/ Operating Scenario


Testing Method


Requirements

1. Nitrogen Oxides (NOx)


2

3-Hour Average

EUBOILER9

Section VI.15, 19

Performance test established

by 40 CFR 60.8

40 CFR Part 60 Subparts A

& D



2



a. Test Protocol

b. Test Protocol

EUBOILER9

Section V Section VII.8

a. R 336.1331 40 CFR Part

60 Subparts A & D

R336.1201(3) b. Civil

Action No. 03-C-0371

Paragraph 89 3. Sulfur

Oxides (SOx)

1.2 lbs / MMBTU heat input2 3-Hour

Average

EUBOILER9 Section VI.15, 19

Performance test established

by 40 CFR 60.8

R336.1201(3) 40 CFR Part

60 Subparts A & D


20% opacity, except as specified in 40 CFR Part 60

Subparts A & D2


R 336.1301, R336.1201(3) 40 CFR Part

60 Subparts A & D




Page 46 of 93




















indicator of proper operation of the baghouse. The indicator range shall be as specified in the most recent




Page 47 of 93

CAM Plan and based on a 3-hr block average, excluding those events defined as startup, shutdown or malfunction. (40 CFR 64.6(c)(1)(i and ii))







specified in 40 CFR 64.7 through 40 CFR 64.9. (40 CFR 64.6(c)(3), 40 CFR 64.7(a)) 6. An excursion is a departure from the indicator range specified in the most recent CAM Plan for pressure









repair of the monitoring equipment. (40 CFR 64.7(b)) OPACITY MONITORING




Page 48 of 93

12. The permittee shall calibrate, monitor, and record visible emissions on a continuous basis, with certified instrumentation, and in a manner acceptable to the Air Quality Division.

2 (R 336.1201(3), 40 CFR 60.13,

40 CFR Part 60 Appendix B Performance Specification 1) 13. Within 30 days following the end of each calendar quarter, the permittee shall submit an excess emissions

report (EER).2 (R 336.1201(3), 40 CFR 60.7 (c) and (d))



(R 336.1201(3), USEPA Publication 450/4-92-010 Performance Audit Procedures for Opacity Monitors) GASEOUS EMISSIONS MONITORING 15. The permittee shall calibrate, monitor, and record SO2 and NOx emissions on a continuous basis, with


60.13, 40 CFR Part 60 Appendix B Performance Specification 2, 40 CFR Part 75, R 336.1801) 16. For the three-hour average SO2 and NOx emission limits specified under EMISSION LIMITS above, excess

emissions are defined as any three-hour period during which the average emissions (arithmetic average of the three contiguous one-hour periods as measured by the continuous monitoring system) exceed the emission limit.

2 (R 336.1201(3), 40 CFR 60.45(g)(2) and (3))


report (EER) for SO2 and NOx.2 (R 336.1201(3), 40 CFR 60.7(c) and (d), 40 CFR Part 75)





emissions or sulfur content of the fuel, rate of fuel burned, heating value, ash content, average electrical output, and minimum and maximum hourly generation rate. See Appendix 4

2 (R336.1201(3)), (40 CFR Part

60 Subparts A and D, 40 CFR Part 75) VII. REPORTING









duration and cause of excursions and/or exceedances and the corrective actions taken. If there were no




Page 49 of 93

excursions and/or exceedances in the reporting period, then this report shall include a statement that there were no excursions and/or exceedances. (40 CFR 64.9(a)(2)(i))








Dimensions (inches)


Ground (feet)


1. SVFLUE9 1141 410

1 R 336.1201(3)


1. The permittee shall comply with all applicable requirements of 40 CFR Part 64 and implement the submitted





exclusive use, of any credible evidence or information, relevant to whether a source would have been in compliance with applicable requirements if the appropriate performance or compliance test or procedure had been performed. Division.

2 (40 CFR 60.11(g))




allowances that an affected source lawfully holds as of the allowance transfer deadline pursuant to R 336.1299(d) and 40 CFR 72.9(c)(1)(i). (R336.1213(10))


96.288, as adopted and modified by R 336.1420, and as outlined in any complete CAIR SO2 permit issued by




Page 50 of 93

the AQD. CAIR SO2 Permit No. MI-SO2-1769-20XX is hereby incorporated into this ROP as Appendix 10. (R 336.1420)




















Page 51 of 93

EUASHHANDLING EMISSION UNIT CONDITIONS

DESCRIPTION Various ash handling processes throughout the plant complex, including flyash unloaders; flyash transfer from electrostatic precipitator and baghouse hoppers to day silos, and to storage silos for off-season storage of flyash. Flyash transfer operations and storage silos are controlled with concentric loading/venting systems and/or baghouse dust collectors. Ash handling methods incorporate dust control measures and work practices as specified in the Fugitive Dust Minimization Plan. Flexible Group ID: NA

POLLUTION CONTROL EQUIPMENT Loading/Venting Systems and/or Baghouse Dust Collectors. I. EMISSION LIMITS

Pollutant Limit Time Period/ Operating Scenario Equipment

Monitoring/ Testing Method


Requirements 1.Particulate Matter (PM)

0.1 lbs. per 1,000 lbs. of

exhaust gases

Instantaneous EUASHHANDLING Section V.1, Section VI.1

R336.1331(1)(a)

II. MATERIAL LIMITS 1. NA

III. PROCESS/OPERATIONAL RESTRICTIONS 1. NA


V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. The permittee shall use trained plant staff to conduct and record visible emissions observations of each ash

handling system baghouse exhaust stack at least once per week during routine operating conditions if the source is in operation during the week. Any visible emissions shall result in documented corrective action. (R336.1213(3))

VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))




Page 52 of 93

1. The permittee shall conduct weekly visible emission observations, at emission points, by trained plant staff to assure compliance with R336.1301 and R336.1901. The permittee shall keep records (presence or absence of visible emissions, date, time, name of the reader, certified or not, any corrective actions taken if visible emissions observed) of such observations The permittee shall monitor and record visible emission observations in accordance with USEPA Method 9 at the request of the MDEQ. (R336.1213(3), R336.1303)

VII. REPORTING

1. Prompt reporting of deviations pursuant to General Conditions 21 and 22 of Part A. (R 336.1213(3)(c)(ii)) 2. Semiannual reporting of monitoring and deviations pursuant to General Condition 23 of Part A. The report

shall be postmarked or received by the appropriate AQD District Office by March 15 for reporting period July 1 to December 31 and September 15 for reporting period January 1 to June 30. (R 336.1213(3)(c)(i))

3. Annual certification of compliance pursuant to General Conditions 19 and 20 of Part A. The report shall be

postmarked or received by the appropriate AQD District Office by March 15 for the previous calendar year. (R 336.1213(4)(c))


1. NA


1. The permittee shall operate the flyash storage, unloading, and handling systems in accordance with the

program for continuous fugitive emissions control specified in the Fugitive Dust Minimization Plan. (R 336.1213(3))

2. The permittee shall transport all flyash in equipment that is covered or which is demonstrated, to the

satisfaction of the District Supervisor, to have dust control equivalent to covered equipment.2 (R 336.1201(3))

Footnotes: 1This condition is state only enforceable and was established pursuant to Rule 201(1)(b).





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EUMATERIALHANDLING EMISSION UNIT CONDITIONS

DESCRIPTION Various material handling processes throughout the plant complex, including the Ship Unloading Facility, outdoor fuel storage piles, limestone handling, plant yard and roadways, radial arm stacker, and coal transfer into the power plant boilers’ coal bunkers. Dust control measures include cyclonic and fabric filter dust collectors, wet dust collectors, sweeping, flushing, water sprays, dust suppressants, enclosures, barriers, and work practices as specified in the Fugitive Dust Minimization Plan. Flexible Group ID: NA

POLLUTION CONTROL EQUIPMENT Dust control measures include cyclonic and fabric filter dust collectors, wet dust collectors, sweeping, flushing, water sprays, dust suppressants, enclosures, barriers, and work practices as specified in the Fugitive Dust Minimization Plan. I. EMISSION LIMITS


Operating Scenario


Testing Method


Requirements 1.Particulate Matter (PM)

0.1 lbs. per 1,000 lbs. of exhaust

gases

Instantaneous EUMATERIALHANDLING Section V.1, Section VI.1

R336.1331(1)(a)

II. MATERIAL LIMITS 1. NA

III. PROCESS/OPERATIONAL RESTRICTIONS 1. NA


V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. NA VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. The permittee shall conduct weekly visible emission observations, at emission points, either by a USEPA

Method 9 certified reader or by a non-certified reader, to assure compliance with R336.1301 and R336.1901. The permittee shall keep records (presence or absence of visible emissions, date, time, name of the reader, certified or not, any corrective actions taken if visible emissions observed) of such observations The




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permittee shall monitor and record visible emission observations in accordance with USEPA Method 9 at the request of the MDEQ. (R336.1213(3), R336.1303)

VII. REPORTING

1. Prompt reporting of deviations pursuant to General Conditions 21 and 22 of Part A. (R 336.1213(3)(c)(ii)) 2. Semiannual reporting of monitoring and deviations pursuant to General Condition 23 of Part A. The report





1. NA


1. The permittee shall operate the coal handling systems and the Ship Unloading Facility in accordance with the

program for continuous fugitive emissions control for all plant roadways, the plant yard, all material storage piles, and all material handling operations specified in the Fugitive Dust Minimization Plan. (R 336.1213(3))

2. The permittee shall maintain the dust suppression spray systems on the Ship Unloading Facility, including at

the vessel boom receiving hopper and at the stacker boom, and shall not operate the unloading equipment unless the dust control equipment is available and utilized when needed. The equipment shall be maintained to prevent malfunction and freeze up. Water sprays located on an unloading vessel and used for dust suppression may be considered part of the Ship Unloading Facility dust suppression spray system.

2

(R336.1213(3), (R 336.1201(3)) 3. The permittee shall maintain a 10-foot high fence of a type approved by the Air Quality Division along the east

and north boundaries of the bulk material storage area.2 (R 336.1201(3))

4. The height of the coal storage pile shall not exceed 60 feet and the pile shapes shall be maintained in a

configuration, providing that sufficient coal is available for “dead storage”, which provides an acceptable physical barrier around the perimeter of the coal storage area above the level of the piles on which mobile equipment is normally operating. The physical barriers shall be compacted and maintained with a chemical encrusting agent.

2 (R 336.1201(3)) (R336.1213(3)) 5. The permittee shall maintain the outer slopes of the coal storage pile at an angle not exceeding 30 degrees.

The coal in the outer slopes shall be compacted and maintained with a chemical encrusting agent.2

(R 336.1201(3)), (R336.1213(3)) 6. Whenever the operation of mobile equipment on a coal storage pile is likely to generate fugitive dust

emissions, a liquid dust suppressant shall be applied to the area of the pile on which the equipment is utilized, except during freezing conditions.

2 (R 336.1201(3)) 7. Whenever the probability of fugitive dust exists, a liquid dust suppressant shall be applied to those portions of

the coal storage pile from which fugitive dust emissions are likely to emanate, except during freezing conditions.

2 (R 336.1201(3))




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8. All coal located under the stacker boom of the ship unloading system shall be stockpiled as soon as possible subsequent to its unloading from a ship, consistent with the hours of operation specified in this ROP, Section IX-Condition 9 below.

2 (R 336.1201(3)) 9. Mobile equipment for transporting, stockpiling, and reclaiming coal, working the coal storage pile, and

removing coal from under the stacker boom of the ship unloading system may be operated between 6:00 a.m. and 10:00 p.m. daily. Between 10:00 p.m. to 6:00 a.m., coal reclaiming to the plant may also take place but only rubber-tired mobile equipment may be used. Notwithstanding this operation limitation, any and all equipment may be operated to respond to an emergency that threatens the safety or operation of the plant.

1

(R336.1213(3)),(R 336.1201(3))

10. The permittee shall maintain rubber tired mobile equipment for the use of working on the coal storage pile. Metal track-type mobile equipment may be used to assist in coal handling under the stacker boom of the ship unloading system on loose coal from ship unloading, reclaiming operation, coal pile maintenance, and grooming.

2 (R336.1213(3)), (R 336.1201(3)) 11. The permittee shall employ teams, who are responsible for implementing of the fugitive dust control program,

for each shift during which coal is added to or taken from a coal storage pile. The teams on duty shall be supplied with operable electronic communication capabilities so that continuous weather forecasts are available.

2 (R336.1213(3)), (R 336.1201(3)) 12. All personnel responsible for coal handling shall be instructed in the appropriate procedures for maintaining

compliance with all permit conditions.2 (R336.1213(3)), (R 336.1201(3))

13. The permittee shall maintain the Ship Unloading Facility main conveyor belt total enclosure to prevent

particulate fallout on either public or company property.2 (R 336.1201(3))

14. The permittee shall operate the Ship Unloading Facility radial stacker in a manner which will minimize the free

fall distance of the material being handled.2 (R 336.1201(3))

15. The Ship Unloading Facility main receiving bin shall be structurally maintained in order to accommodate

partial enclosure of the ship’s boom should such enclosure be necessary to reduce dust emissions.2

(R 336.1201(3)) Footnotes: 1This condition is state only enforceable and was established pursuant to Rule 201(1)(b).





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EUICDIESEL2 EMISSION UNIT CONDITIONS

DESCRIPTION Existing, Diesel fired, Compression Ignition, Emergency, Stationary, more than 500 BHP, Reciprocating Internal Combustion Engine, located at a major source of HAP emissions, subject to 40 CFR 63, Subpart ZZZZ-National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Flexible Group ID: NA

POLLUTION CONTROL EQUIPMENT : NA

I. EMISSION LIMITS: NA

II. MATERIAL LIMITS: NA

III. PROCESS/OPERATIONAL RESTRICTIONS: NA

IV. DESIGN/EQUIPMENT PARAMETERS: NA

V. TESTING/SAMPLING

Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. NA

VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. NA

VII. REPORTING 1. Prompt reporting of deviations pursuant to General Conditions 21 and 22 of Part A. (R 336.1213(3)(c)(ii)) 2. Semiannual reporting of monitoring and deviations pursuant to General Condition 23 of Part A. The report shall

be postmarked or received by the appropriate AQD District Office by March 15 for reporting period July 1 to December 31 and September 15 for reporting period January 1 to June 30. (R 336.1213(3)(c)(i))



See Appendix 8 VIII. STACK/VENT RESTRICTIONS: NA




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1. The permittee shall comply with all applicable provisions of the National Emission Standards for Hazardous Air Pollutants, as specified in 40 CFR, Part 63, Subparts A-General Provisions and ZZZZ- National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. (R 336.1213), (40 CFR Part 63 Subparts A and ZZZZ)

Footnotes: 1 This condition is state only enforceable and was established pursuant to Rule 201(1)(b).

2 This condition is federally enforceable and was established pursuant to Rule 201(1)(a).




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D. FLEXIBLE GROUP CONDITIONS

Part D outlines the terms and conditions that apply to more than one emission unit. The permittee is subject to the special conditions for each flexible group in addition to the General Conditions in Part A and any other terms and conditions contained in this ROP. The permittee shall comply with all specific details in the special conditions and the underlying applicable requirements cited. If a specific condition type does not apply, NA (not applicable) has been used in the table. If there are no special conditions that apply to more than one emission unit, this section will be left blank.

FLEXIBLE GROUP SUMMARY TABLE The descriptions provided below are for informational purposes and do not constitute enforceable conditions.

Flexible Group ID Flexible Group Description Associated Emission Unit IDs

FGICDIESELS Two Existing, Diesel fired, Compression Ignition, Emergency, Stationary, less than 500 HP, Reciprocating Internal Combustion Engines subject to 40 CFR 63, Subpart ZZZZ-National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines

EUICDIESEL1, EUICDIESEL3




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FGICDIESELS FLEXIBLE GROUP CONDITIONS

DESCRIPTION Two Existing, Diesel fired, Compression Ignition, Emergency, Stationary, less than 500 BHP, Reciprocating Internal Combustion Engines, located at a major source of HAP emissions, subject to 40 CFR 63, Subpart ZZZZ-National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines Emission Units: EUICDIESEL1, EUICDIESEL3 POLLUTION CONTROL EQUIPMENT 1. NA

I. EMISSION LIMITS 1. NA

II. MATERIAL LIMITS

1. NA

III. PROCESS/OPERATIONAL RESTRICTIONS 1. FGICDIESELS must comply with the applicable emission limitations and operating limitations in 40 CFR 63, Subpart

ZZZZ no later than May 3, 2013. (40 CFR 63.6595(a)) 2. Permittee must operate and maintain the stationary RICE and after-treatment control device (if any) according to the

manufacturer's emission-related written instructions or develop permittee’s own maintenance plan which must provide to the extent practicable for the maintenance and operation of the engine in a manner consistent with good air pollution control practice for minimizing emissions. (40 CFR 63.6625(e)(2)), (40 CFR 63.6625(i)), (40 CFR 6640(a))

3. The permittee shall operate and maintain, at all times, any affected CI RICE, including associated air pollution

control equipment and monitoring equipment, in a manner consistent with safety and good air pollution control practices for minimizing emissions. The general duty to minimize emissions does not require permittee to make any further efforts to reduce emissions if levels required by this standard have been achieved. Determination of whether such operation and maintenance procedures are being used will be based on information available to the Administrator which may include, but is not limited to, monitoring results, review of operation and maintenance procedures, review of operation and maintenance records, and inspection of the source. (40 CFR 63.6605(b))

4. The permittee shall comply with the following requirements, except during periods of startup:

a) Change oil and filter every 500 hours of operation or annually, whichever comes first, except as allowed in SC III.5.

b) Inspect air cleaner every 1,000 hours of operation or annually, whichever comes first. c) Inspect all hoses and belts every 500 hours of operation or annually, whichever comes first, and replace as

necessary. (40 CFR 63.6602, Table 2c to 40 CFR 63, Subpart ZZZZ)




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Note: If the emergency engine is operating during an emergency and it is not possible to shut down the engine in order to perform the work practice requirements on the schedule required in SC III.4, the work practice should be performed as soon as practicable after the emergency has ended.

5. The permittee may utilize an oil analysis program in order to extend the specified oil change requirement in 40 CFR 63.6602 and as listed in SC III 4(a). If utilized, the oil analysis program must be part of the maintenance plan for the engine. The oil analysis program must be performed at the same frequency as oil changes are required. The analysis program must analyze the parameters and keep records as required in 63.6625(i). (40 CFR 63.6625(i))

6. The permittee must minimize the engine's time spent at idle during startup and minimize the engine's startup

time to a period needed for appropriate and safe loading of the engine, not to exceed 30 minutes, after which time the emission standards applicable to all times other than startup in Tables 1a, 2a, 2c, and 2d of 40 CFR 63, Subpart ZZZZ. (40 CFR 63.6625(h))

7. The permittee shall not allow the CI engine(s) to exceed 100 hours for Maintenance checks and readiness

testing. The owner or operator may petition the Administrator for approval of additional hours to be used for maintenance checks and readiness testing, but a petition is not required if the owner or operator maintains records indicating that Federal, State, or local standards require maintenance and testing of emergency RICE beyond 100 hours per year. (40 CFR 63.6640(f)(1)(ii))

8. The permittee shall not allow the CI engine(s) to operate more than 50 hours per year for non-emergency

situations, as allowed in 40 CFR 63.6640(f)(1)(iii). (40 CFR 63.6640(f)(1)(iii)) IV. DESIGN/EQUIPMENT PARAMETERS 1. The permittee shall install a non-resettable hour meter to each engine, if one is not already installed. (R336.1213(3)),

(40 CFR 63.6625 (f))

V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. If using the oil analysis program for CI Engine(s), the permittee shall test for Total Base Number, viscosity and

percent water content. The condemning limits for these parameters are as follows: Total Base Number is less than 30 percent of the Total Base Number of the oil when new; viscosity of the oil has changed by more than 20 percent from the viscosity of the oil when new; or percent water content (by volume) is greater than 0.5. (40 CFR 63.6625(i))

VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii)) 1. The permittee must keep records of the hours of operation of each engine that is recorded through the non-

resettable hour meter. The permittee must document:

a) How many hours are spent for emergency operation? b) What classified the operation as emergency? c) How many hours are spent for non-emergency operation? d) If the engines are used for demand response operation, the permittee must keep records of the notification

of the emergency situation, and the time the engine was operated as part of demand response. (40 CFR 63.6655(f), 40 CFR 63.6660)

2. The permittee shall keep records for each CI engine of the occurrence and duration of each malfunction of operation (i.e., process equipment) or the air pollution control and monitoring equipment. (40 CFR 63.6655(a)(2), 40 CFR 63.6660)

3. The permittee shall keep records of all required maintenance performed on the air pollution control and monitoring equipment. (40 CFR 63.6655(a)(4), 40 CFR 63.6660)




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4. The permittee shall keep records of actions taken during periods of malfunction to minimize emissions in accordance with 63.6605(b), including corrective actions to restore malfunctioning process and air pollution control and monitoring equipment to its normal or usual manner of operation. (40 CFR 63.6655(a)(5), 40 CFR 63.6660)

5. The permittee must keep records of the parameters that are analyzed as part of the oil analysis program, the results of the analysis, and the oil changes for the engine. The records shall be kept for 5 years. (40 CFR 63.6625(i))

6. The permittee shall keep the records required in 40 CFR 63.6655(d) and 63.6655(e). The records shall be kept for 5 years. (40 CFR 63.6655(d), 40 CFR 63.6655(e), 40 CFR 63.6660)

VII. REPORTING 1. Prompt reporting of deviations pursuant to General Conditions 21 and 22 of Part A. (R 336.1213(3)(c)(ii)) 2. Semiannual reporting of monitoring and deviations pursuant to General Condition 23 of Part A. The report





1. NA


1. The permittee shall comply with all applicable provisions of the National Emission Standards for Hazardous Air Pollutants, as specified in 40 CFR, Part 63, Subparts A-General Provisions and ZZZZ- National Emissions Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines. (R 336.1213), (40 CFR Part 63 Subparts A and ZZZZ)

2. If all of the condemning limits specified in SC V.1 are not exceeded, the permittee is not required to change the

oil. If any of the limits are exceeded, the permittee must change the oil within 2 days of receiving the results of the analysis; if the engine is not in operation when the results of the analysis are received, the permittee must change the oil within 2 days or before commencing operation, whichever is later. (40 CFR 63.6625(i))

Footnotes: 1This condition is state only enforceable and was established pursuant to Rule 201(1)(b).





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E. NON-APPLICABLE REQUIREMENTS At the time of the ROP issuance, the AQD has determined that the requirements identified in the table below are not applicable to the specified emission unit(s) and/or flexible group(s). This determination is incorporated into the permit shield provisions set forth in the General Conditions in Part A pursuant to Rule 213(6)(a)(ii). If the permittee makes a change that affects the basis of the non-applicability determination, the permit shield established as a result of that non-applicability decision is no longer valid for that emission unit or flexible group.

Emission Unit/Flexible Group ID Non-Applicable Requirement Justification

EUBOILER5 EUBOILER6 EUBOILER7 EUBOILER8 EUBOILER9

40 CFR Part 63- Subpart DDDDD -

National Emission Standards for Hazardous Air Pollutants for Industrial, Commercial, and

Institutional Boilers and Process Heaters

40 CFR 63 Subpart DDDDD does not apply to Boilers #5 through #9 because these boilers serve generators with nameplate capacities greater than 25 megawatts. “The types of boilers and process heaters listed in paragraphs (a) through (o) of this section are not subject to this subpart… (c) An electric utility steam generating unit that is a fossil fuel-fired combustion unit of more than 25 megawatts that serves a generator that produces electricity for sale…” (40 CFR 63.7491)

EUICDIESEL2 40 CFR 63, Subpart ZZZZ-

National Emissions Standards for Hazardous Air Pollutants for

Stationary Reciprocating Internal Combustion Engines

40 CFR 63, Subpart A- General Provisions

Emergency Diesel Generator for Boiler Units 7-9 (Constructed January 1977, 710 hp) is an existing (constructed before December 19, 2002), stationary RICE with a site rating of more than 500 brake horse power located at a major source of HAP emissions. Currently, EUICEDIESEL2 does not have to meet the requirements of 40 CFR 63, Subpart ZZZZ and 40 CFR 63, Subpart A. (40 CFR 63.6590(b)(3)(iii))




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APPENDICES

Appendix 1. Abbreviations and Acronyms The following is an alphabetical listing of abbreviations/acronyms that may be used in this permit.

AQD Air Quality Division MM Million acfm Actual cubic feet per minute MSDS Material Safety Data Sheet BACT Best Available Control

Technology MW Megawatts

BTU British Thermal Unit NA Not Applicable °C Degrees Celsius NAAQS National Ambient Air Quality Standards CAA Federal Clean Air Act NESHAP National Emission Standard for Hazardous Air Pollutants CAM Compliance Assurance

Monitoring NMOC Non-methane Organic Compounds

CEM Continuous Emission Monitoring NOx Oxides of Nitrogen CFR Code of Federal Regulations NSPS New Source Performance Standards CO Carbon Monoxide NSR New Source Review COM Continuous Opacity Monitoring PM Particulate Matter department Michigan Department of

Environmental Quality PM-10 Particulate Matter less than 10 microns in diameter

dscf Dry standard cubic foot pph Pound per hour dscm Dry standard cubic meter ppm Parts per million EPA United States Environmental

Protection Agency ppmv Parts per million by volume

EU Emission Unit ppmw Parts per million by weight °F Degrees Fahrenheit PS Performance Specification FG Flexible Group PSD Prevention of Significant Deterioration GACS Gallon of Applied Coating Solids psia Pounds per square inch absolute GC General Condition psig Pounds per square inch gauge gr Grains PeTE Permanent Total Enclosure HAP Hazardous Air Pollutant PTI Permit to Install Hg Mercury RACT Reasonable Available Control Technology hr Hour ROP Renewable Operating Permit HP Horsepower SC Special Condition H2S Hydrogen Sulfide scf Standard cubic feet HVLP High Volume Low Pressure * sec Seconds ID Identification (Number) SCR Selective Catalytic Reduction IRSL Initial Risk Screening Level SO2 Sulfur Dioxide ITSL Initial Threshold Screening Level SRN State Registration Number LAER Lowest Achievable Emission Rate TAC Toxic Air Contaminant lb Pound Temp Temperature m Meter THC Total Hydrocarbons MACT Maximum Achievable Control

Technology tpy Tons per year

MAERS Michigan Air Emissions Reporting System

µg Microgram

MAP Malfunction Abatement Plan VE Visible Emissions MDEQ Michigan Department of

Environmental Quality VOC Volatile Organic Compounds

mg Milligram yr Year mm Millimeter

*For HVLP applicators, the pressure measured at the gun air cap shall not exceed 10 pounds per square inch gauge (psig).




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Appendix 2. Schedule of Compliance The permittee certified in the ROP application that this stationary source is in compliance with all applicable requirements and the permittee shall continue to comply with all terms and conditions of this ROP. A Schedule of Compliance is not required. (R 336.1213(4)(a), R 336.1119(a)(ii))

Appendix 3. Monitoring Requirements Specific monitoring requirement procedures, methods or specifications are detailed in Part A or the appropriate Source-Wide, Emission Unit and/or Flexible Group Special Conditions. Therefore, this appendix is not applicable.

Appendix 4. Recordkeeping The permittee shall use the following approved formats and procedures for the recordkeeping requirements referenced in EUBOILER5, EUBOILER6, EUBOILER7, EUBOILER8, & EUBOILER9. Alternative formats must be approved by the AQD District Supervisor. Coal Analysis

(a) For each coal shipment received, the permittee shall obtain from the supplier a laboratory analysis of the ash content, sulfur content, and BTU content. The determination of sulfur content shall be carried out in accordance with a procedure acceptable to the Air Quality Division. For each coal shipment received, the permittee shall record the date received, source of coal and shipper, and tons received.

Appendix 5. Testing Procedures Specific testing requirement plans, procedures, and averaging times are detailed in the appropriate Source-Wide, Emission Unit and/or Flexible Group Special Conditions. Therefore, this appendix is not applicable.

Appendix 6. Permits to Install The following table lists any PTIs issued since the effective date of previously issued ROP No. MI-ROP-B4261-2007. This includes any PTIs that were incorporated into the Source-Wide PTI No MI-PTI-B4261-2007 through amendments or modifications and any PTI that remained off-permit until this ROP renewal. Source-Wide PTI No MI-PTI-B4261-2007 is being reissued as Source-Wide PTI No. MI-PTI-B4261-{201X}.

Permit to Install Number Description of Equipment or Change Corresponding Emission Unit(s) or

Flexible Group(s) None

Appendix 7. Emission Calculations Specific emission calculations to be used with monitoring, testing or recordkeeping data are detailed in the appropriate Source-Wide, Emission Unit and/or Flexible group Special Conditions. Therefore, this appendix is not applicable.




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Appendix 8. Reporting A. Annual, Semiannual, and Deviation Certification Reporting The permittee shall use the MDEQ Report Certification form (EQP 5736) and MDEQ Deviation Report form (EQP 5737) for the annual, semiannual and deviation certification reporting referenced in the Reporting Section of the Source-Wide, Emission Unit and/or Flexible Group Special Conditions. Alternative formats must meet the provisions of Rule 213(4)(c) and Rule 213(3)(c)(i), respectively, and be approved by the AQD District Supervisor. B. Other Reporting Specific reporting requirement formats and procedures are detailed in Part A or the appropriate Source-Wide, Emission Unit and/or Flexible Group Special Conditions. Therefore, Part B of this appendix is not applicable.




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Appendix 9. Phase II Acid Rain Permit

Michigan Department Of Environmental Quality Air Quality Division

PHASE II ACID RAIN PERMIT Permit No. MI-AR-1769-20XX

Permittee WE Energies – Presque Isle Power Plant Address 2701 Lakeshore Blvd. N., Marquette, Michigan SRN B4261 ORIS code 1769 Issue Date DRAFT Effective: Issuance date of this facility’s Renewable Operating Permit at

the facility in accordance with 40 CFR 72.73. Expiration This permit shall expire when the facility’s Renewable

Operating Permit expires, in accordance with 40 CFR 72.73. ROP No. MI-ROP-B4261-20XX

The Acid Rain Permit Contents 1. A statement of basis prepared by the Air Quality Division (AQD) containing:

References to statutory and regulatory authorities, and with comments, notes, and justification that apply to the source in general;

2. Terms and conditions including:

A table of sulfur dioxide allowances to be allocated during the term of the permit, if applicable, authorized by this permit during Phase II. Unless they are subject to sections 405(g)(2) or (3) of the Clean Air Act, new units are not allocated allowances in 40 CFR part 73 and must obtain allowances by other means (sec. 403(e) of the Clean Air Act).; Comments, notes and justifications regarding permit decisions and changes made to the permit application forms during the review process, and any additional requirements; and, Any applicable nitrogen oxides compliance plan. Unless they are coal fired utility units regulated pursuant to sections 404, 405, or 409 of the Clean Air Act, new units are not subject to the acid rain nitrogen oxides requirements [40 CFR 76.1(a)].

3. The permit application that this source submitted, as corrected by the AQD. The

owners and operators of the source must comply with the standard requirements and special provisions set forth in the application.




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Statement of Basis Statutory and Regulatory Authorities. In accordance with the Natural Resources and Environmental Protection Act, 1994 PA 451 and Titles IV and V of the Clean Air Act, the Michigan Department of Environmental Quality, Air Quality Division (AQD), issues this permit pursuant to the provisions of R 336.1210 to R 336.1218, and R 336.1299(d).

For further information contact: Brian Carley Environmental Quality Specialist

Michigan Department of Environmental Quality Air Quality Division 301 Louis Glick Highway Jackson, Michigan 49201 Telephone: (517) 780-7843 Facsimile: (517) 780-7437

There are no comments, notes and/or justification that apply to the source in general for this section.




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Terms and Conditions: Phase II Sulfur Dioxide Allowance Allocation and Nitrogen Oxides Requirements for each affected unit.

2012 2013 2014 2015 2016

Unit #5

SO2 allowances

2938 2938 2938 2938 2938

NOx Limit

NOx limit Pursuant to 40 CFR 76.11, the State of Michigan Department of Environmental Quality, Air Quality Division approves a NOx emissions averaging plan for this unit, effective from calendar years 2008 through 2013. Under the plan, this unit’s NOx emissions shall not exceed the annual average alternative contemporaneous emission limitation of 0.50 lb/mmBtu. In addition, this unit shall not have an annual heat input greater than 6,600,000 mmBtu.

Under the plan, the actual Btu-weighted annual average NOx emission rate for the units in the plan shall be less than or equal to the Btu-weighted annual average NOx emission rate for the same units had they each been operated, during the same period of time, in compliance with the applicable emission limitations under 40 CFR 76.5, 76.6, or 76.7, except that for any early election units, the applicable emission limitations shall be under 40 CFR 76.7. If the designated representative demonstrates that the requirement of the prior sentence (as set forth in 40 CFR 76.11(d)(1)(ii)(A)) is met for a year under the plan, then this unit shall be deemed to be in compliance for that year with its alternative contemporaneous annual emission limitation and annual heat input limit. In accordance with 40 CFR 72.40(b)(2), approval of the averaging plan shall be final only when the Wisconsin Department of Natural Resources has also approved this averaging plan. In addition to the described NOX compliance plan, this unit shall comply with all other applicable requirements of 40 CFR part 76, including the duty to reapply for a NOX compliance plan and requirements covering excess emissions.




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Terms and Conditions (continued):

2012 2013 2014 2015 2016

Unit #6

SO2 allowances

2946 2946 2946 2946 2946

NOx limit






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2012 2013 2014 2015 2016

Unit #7

SO2 allowances

2173 2173 2173 2173 2173

NOx Limit






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2012 2013 2014 2015 2016

Unit #8

SO2 allowances

2050 2050 2050 2050 2050

NOx Limit






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2012 2013 2014 2015 2016

Unit #9

SO2 allowances

1511 1511 1511 1511 1511

NOx Limit



Comments, notes and justifications regarding permit decisions, and changes made to the permit application forms during the review process: Units 3 and 4 of the Presque Isle Power Plant were retired on October 1, 2009. They are no longer considered as part of the NOx Compliance Plan and the NOx Averaging Plan for this facility. They will be removed from those plans after the current plans expire in 2013 and they submit renewed versions of those plans.

Permit Application: (attached) Acid Rain Permit Application submitted October 17, 2011 Phase II NOx Compliance Plan submitted September 22, 2008 Phase II NOx Averaging Plan submitted September 22, 2008




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Appendix 10. CAIR Sulfur Dioxide Budget Permit


CAIR Sulfur Dioxide Budget Permit Permit No. MI-SO2-1769-20XX

Permittee WE Energies – Presque Isle Power Plant Address 2701 Lakeshore Blvd. N., Marquette, Michigan SRN B4261 ORIS code 1769 Issue Date DRAFT Expiration This permit shall expire when the facility’s Renewable

Operating Permit (ROP) expires in accordance with 40 CFR 97.221(b).

ROP No. MI-ROP-B4261-20XX This permit incorporates automatically the definitions of terms under Air Pollution Control Rule 336.1420. This permit incorporates automatically, upon recordation by the EPA Administrator in accordance with 40 CFR part 97 subpart FFF, GGG, or III every allocation, transfer, or deduction of a SO2 allowance to or from the compliance accounts of the CAIR SO2 unit(s) covered by the permit. The owners and operators of the source must comply with the standard requirements and special provisions set forth in this permit. This permit incorporates any attached comments, notes or justifications regarding permit decisions and changes made to the permit application forms during the review process.

Units covered under this permit AQD Unit ID Unit Type

EUBOILER 5 X Stationary Boiler Combined Cycle System

Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other

Permit Application: CAIR SO2 Annual Permit application submitted October 17, 2011




Page 86 of 93

Standard requirements (a) Permit requirements. (1) The CAIR designated representative of each CAIR SO2 source required to have a ROP and each CAIR SO2 unit required to have a ROP at the source shall: (i) Submit to the permitting authority a complete CAIR permit application under § 97.222 in accordance

with the deadlines specified in § 97.221; and (ii) Submit in a timely manner any supplemental information that the permitting authority determines is

necessary in order to review a CAIR permit application and issue or deny a CAIR permit. (2) The owners and operators of each CAIR SO2 source required to have a ROP and each CAIR SO2 unit required to have a ROP at the source shall have a CAIR permit issued by the permitting authority under subpart CCC of 40 CFR part 97 for the source and operate the source and the unit in compliance with such CAIR permit. (b) Monitoring, Reporting, and Recordkeeping Requirements. (1) The owners and operators, and the CAIR designated representative, of each CAIR SO2 source and each CAIR SO2 unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of subpart HHH of 40 CFR part 97. (2) The emissions measurements recorded and reported in accordance with subpart HHH of 40 CFR part 97 shall be used to determine compliance by each CAIR SO2 source with the CAIR SO2 emissions limitation under paragraph (c) of this permit. (c) Sulfur Dioxide Emission Requirements. (1) As of the allowance transfer deadline for a control period, the owners and operators of each CAIR SO2 source and each CAIR SO2 unit at the source shall hold, in the source’s compliance account, a tonnage equivalent in CAIR SO2 allowances available for compliance deductions for the control period, as determined in accordance with § 97.254(a) and (b), not less than the tons of total sulfur dioxide emissions for the control period from all CAIR SO2 units at the source, as determined in accordance with subpart HHH of 40 CFR part 97. (2) A CAIR SO2 unit shall be subject to the requirements under paragraph (c)(1) of this section for the control period starting on the later of January 1, 2010 or the deadline for meeting the unit(s monitor certification requirements under § 97.270(b)(1),(2), or (5) and for each control period thereafter. (3) A CAIR SO2 allowance shall not be deducted, for compliance with the requirements under paragraph (c)(1) of this section, for a control period in a calendar year before the year for which the CAIR SO2 allowance was allocated. (4) CAIR SO2 allowances shall be held in, deducted from, or transferred into or among CAIR SO2 Allowance Tracking System accounts in accordance with subparts FFF, GGG, and III of 40 CFR part 97. (5) A CAIR SO2 allowance is a limited authorization to emit sulfur dioxide in accordance with the CAIR SO2 Trading Program. No provision of the CAIR SO2 Trading Program, the CAIR permit application, the CAIR permit, or an exemption under § 97.205 and no provision of law shall be construed to limit the authority of the United States to terminate or limit such authorization. (6) A CAIR SO2 allowance does not constitute a property right. (7) Upon recordation by the Administrator under subpart FFF, GGG, or III of 40 CFR part 97, every allocation, transfer, or deduction of a CAIR SO2 allowance to or from a CAIR SO2 source’s compliance account is incorporated automatically in any CAIR permit of the source.




Page 87 of 93

(d) Excess emissions requirements. If a CAIR SO2 source emits sulfur dioxide during any control period in excess of the CAIR SO2 emissions limitation, then: (1) The owners and operators of the source and each CAIR SO2 unit at the source shall surrender the CAIR SO2 allowances required for deduction under § 97.254(d)(1) and pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act or applicable State law; and (2) Each ton of such excess emissions and each day of such control period shall constitute a separate violation of this subpart, the Clean Air Act, and applicable State law. (e) Recordkeeping and Reporting Requirements. (1) Unless otherwise provided, the owners and operators of the CAIR SO2 source and each CAIR SO2 unit at the source shall keep on site at the source each of the following documents for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the permitting authority or the Administrator. (i) The certificate of representation under § 97.213 for the CAIR designated representative for the source

and each CAIR SO2 unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such documents are superseded because of the submission of a new certificate of representation under § 97.213 changing the CAIR designated representative.

(ii) All emissions monitoring information, in accordance with subpart HHH of 40 CFR part 97, provided that to the extent that subpart HHH of 40 CFR part 97 provides for a 3-year period for recordkeeping, the 3-year period shall apply. (iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under the CAIR SO2 Trading Program.

(iv) Copies of all documents used to complete a CAIR permit application and any other submission under the CAIR SO2 Trading Program or to demonstrate compliance with the requirements of the CAIR SO2 Trading Program.

(2) The CAIR designated representative of a CAIR SO2 source and each CAIR SO2 unit at the source shall submit the reports required under the CAIR SO2 Trading Program, including those under subpart HHH of 40 CFR part 97. (f) Liability. (1) Each CAIR SO2 source and each CAIR SO2 unit shall meet the requirements of the CAIR SO2 Trading Program. (2) Any provision of the CAIR SO2 Trading Program that applies to a CAIR SO2 source or the CAIR designated representative of a CAIR SO2 source shall also apply to the owners and operators of such source and of the CAIR SO2 units at the source. (3) Any provision of the CAIR SO2 Trading Program that applies to a CAIR SO2 unit or the CAIR designated representative of a CAIR SO2 unit shall also apply to the owners and operators of such unit. (g) Effect On Other Authorities.

No provision of the CAIR SO2 Trading Program, a CAIR permit application, a CAIR permit, or an exemption under § 97.205 shall be construed as exempting or excluding the owners and operators, and the CAIR designated representative, of a CAIR SO2 source or CAIR SO2 unit from compliance with any other provision of the applicable, approved State implementation plan, a federally enforceable permit, or the Clean Air Act.




Page 88 of 93

Appendix 11. CAIR Annual Nitrogen Oxide Budget Permit


CAIR Annual Nitrogen Oxide Budget Permit Permit No. MI-NOA-1769-20XX


Operating Permit expires in accordance with Air Pollution Control Rule 336.1821.

ROP No. MI-ROP-B4261-20XX This permit incorporates automatically the definitions of terms under Air Pollution Control Rule 336.1803. This permit incorporates automatically, upon recordation by the EPA Administrator in accordance with Air Pollution Control Rule 336.1830, 336.1831 and 336.1834 every allocation, transfer, or deduction of a NOx allowance to or from the compliance accounts of the NOx Budget unit(s) covered by the permit. The owners and operators of the source must comply with the standard requirements and special provisions set forth in this permit. This permit incorporates any attached comments, notes or justifications regarding permit decisions and changes made to the permit application forms during the review process.



Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other

Permit Application: CAIR NOx Annual Permit application submitted October 17, 2011




Page 89 of 93

Standard Requirements

(a) Permit Requirements. (1) The CAIR designated representative of each CAIR NOX source required to have a Renewable Operating Permit (ROP) and each CAIR NOX unit required to have a ROP at the source shall:

(i) Submit to the Michigan Department of Environmental Quality, Air Quality Division (MDEQ-AQD) a complete CAIR permit application under R 336.1821(3) in accordance with the deadlines specified in 40 CFR 97.121; and (ii) Submit in a timely manner any supplemental information that the MDEQ-AQD determines is necessary in order to review a CAIR permit application and issue or deny a CAIR permit.

(2) The owners and operators of each CAIR NOX source required to have a ROP and each CAIR NOX unit required to have a ROP at the source shall have a CAIR permit issued by the MDEQ-AQD under subpart CC of 40 CFR part 97 for the source and operate the source and the unit in compliance with such CAIR permit. (b) Monitoring, Reporting, and Recordkeeping Requirements. (1) The owners and operators, and the CAIR designated representative, of each CAIR NOX source and each CAIR NOX unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of subpart HH of 40 CFR part 97. (2) The emissions measurements recorded and reported in accordance with subpart HH of 40 CFR part 97 shall be used to determine compliance by each CAIR NOX source with the CAIR NOX emissions limitation under paragraph (c) of this permit. (c) Nitrogen Oxides Emission Requirements. (1) As of the allowance transfer deadline for a control period, the owners and operators of each CAIR NOX source and each CAIR NOX unit at the source shall hold, in the source’s compliance account, CAIR NOX allowances available for compliance deductions for the control period under 40 CFR 97.154(a) in an amount not less than the tons of total nitrogen oxides emissions for the control period from all CAIR NOX units at the source, as determined in accordance with subpart HH of 40 CFR part 97. (2) A CAIR NOX unit shall be subject to the requirements under paragraph (c)(1) for the control period starting on the later of January 1, 2009 or the deadline for meeting the unit’s monitor certification requirements under 40 CFR 97.170(b)(1), (2), or (5) and for each control period thereafter. (3) A CAIR NOX allowance shall not be deducted, for compliance with the requirements under paragraph (c)(1) of this section, for a control period in a calendar year before the year for which the CAIR NOX allowance was allocated. (4) CAIR NOX allowances shall be held in, deducted from, or transferred into or among CAIR NOX Allowance Tracking System accounts in accordance with subparts EE, FF, GG, or II of 40 CFR part 97. (6) A CAIR NOX allowance is a limited authorization to emit one ton of nitrogen oxides in accordance with the CAIR NOX Annual Trading Program. No provision of the CAIR NOX Annual Trading Program, the CAIR permit application, the CAIR permit, or an exemption under 40 CFR 97.105 and no provision of law shall be construed to limit the authority of the United States to terminate or limit such authorization. (7) A CAIR NOX allowance does not constitute a property right. (8) Upon recordation by the Administrator under subpart EE, FF, GG, or II of 40 CFR part 97, every allocation, transfer, or deduction of a CAIR NOX allowance to or from a CAIR NOX source’s compliance account is incorporated automatically in any CAIR permit of the source. (d) Excess Emissions Requirements.




Page 90 of 93

If a CAIR NOX source emits nitrogen oxides during any control period in excess of the CAIR NOX emissions limitation, then: (1) The owners and operators of the source and each CAIR NOX unit at the source shall surrender the CAIR NOX allowances required for deduction under 40 CFR 97.154(d)(1) and pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act or applicable State law; and (2) Each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, the Clean Air Act, and applicable State rules. (e) Recordkeeping and Reporting Requirements. (1) Unless otherwise provided, the owners and operators of the CAIR NOX source and each CAIR NOX unit at the source shall keep on site at the source each of the following documents for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the MDEQ-AQD or the Administrator.

(i) The certificate of representation under § 97.113 for the CAIR designated representative for the source and each CAIR NOX unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such documents are superseded because of the submission of a new certificate of representation under § 97.113 changing the CAIR designated representative.

(ii) All emissions monitoring information, in accordance with subpart HH of 40 CFR part 97.

(iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under the CAIR NOX Annual Trading Program.

(iv) Copies of all documents used to complete a CAIR permit application and any other submission under the CAIR NOX Annual Trading Program or to demonstrate compliance with the requirements of the CAIR NOX Annual Trading Program.

(2) The CAIR designated representative of a CAIR NOX source and each CAIR NOX unit at the source shall submit the reports required under the CAIR NOX Annual Trading Program, including those under subpart HH of 40 CFR part 97. (f) Liability. (1) Each CAIR NOX source and each CAIR NOX unit shall meet the requirements of the CAIR NOX Annual Trading Program. (2) Any provision of the CAIR NOX Annual Trading Program that applies to a CAIR NOX source or the CAIR designated representative of a CAIR NOX source shall also apply to the owners and operators of such source and of the CAIR NOX units at the source. (3) Any provision of the CAIR NOX Annual Trading Program that applies to a CAIR NOX unit or the CAIR designated representative of a CAIR NOX unit shall also apply to the owners and operators of such unit. (g) Effect on Other Authorities. No provision of the CAIR NOX Annual Trading Program, a CAIR permit application, a CAIR permit, or an exemption under § 97.205 shall be construed as exempting or excluding the owners and operators, and the CAIR designated representative, of a CAIR NOX source or CAIR NOX unit from compliance with any other provision of the applicable, approved State implementation plan, a federally enforceable permit, or the Clean Air Act.




Page 91 of 93

Appendix 12. CAIR Ozone Nitrogen Oxide Budget Permit

Michigan Department Of Environmental Quality

Air Quality Division

CAIR Ozone Nitrogen Oxide Budget Permit Permit No. MI-NOO-1769-20XX


Operating Permit expires in accordance with Air Pollution Control Rule 336.1821.

ROP No. MI-ROP-B4261-20XX This permit incorporates automatically the definitions of terms under Air Pollution Control Rule 336.1803. This permit incorporates automatically, upon recordation by the EPA Administrator in accordance with Air Pollution Control Rule 336.1822, 336.1823 and 336.1834 every allocation, transfer, or deduction of a NOx allowance to or from the compliance accounts of the NOx Budget unit(s) covered by the permit. The owners and operators of the source must comply with the standard requirements and special provisions set forth in this permit. This permit incorporates any attached comments, notes or justifications regarding permit decisions and changes made to the permit application forms during the review process.



Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other


Combustion Turbine

Other

Permit Application: CAIR NOx Ozone Season Permit application submitted October 17, 2011




Standard Requirements

(a) Permit Requirements. (1) The CAIR designated representative of each CAIR NOX source required to have a Renewable Operating Permit (ROP) and each CAIR NOX unit required to have a ROP at the source shall:

(i) Submit to the Michigan Department of Environmental Quality, Air Quality Division (MDEQ-AQD) a complete CAIR permit application under R 336.1821(3) in accordance with the deadlines specified in 40 CFR 97.321; and (ii) Submit in a timely manner any supplemental information that the MDEQ-AQD determines is necessary in order to review a CAIR permit application and issue or deny a CAIR permit.

(2) The owners and operators of each CAIR NOX source required to have a ROP and each CAIR NOX unit required to have a ROP at the source shall have a CAIR permit issued by the MDEQ-AQD under subpart CCCC of 40 CFR part 97 for the source and operate the source and the unit in compliance with such CAIR permit. (b) Monitoring, Reporting, and Recordkeeping Requirements. (1) The owners and operators, and the CAIR designated representative, of each CAIR NOX source and each CAIR NOX unit at the source shall comply with the monitoring, reporting, and recordkeeping requirements of subpart HHHH of 40 CFR part 97. (2) The emissions measurements recorded and reported in accordance with subpart HHHH of 40 CFR part 97 shall be used to determine compliance by each CAIR NOX source with the CAIR NOX emissions limitation under paragraph (c) of this permit. (c) Nitrogen Oxides Emission Requirements. (1) As of the allowance transfer deadline for a control period, the owners and operators of each CAIR NOX source and each CAIR NOX unit at the source shall hold, in the source’s compliance account, CAIR NOX allowances available for compliance deductions for the control period under 40 CFR 97.354(a) in an amount not less than the tons of total nitrogen oxides emissions for the control period from all CAIR NOX units at the source, as determined in accordance with subpart HHHH of 40 CFR part 97. (2) A CAIR NOX unit shall be subject to the requirements under paragraph (c)(1) for the control period starting on the later of January 1, 2009 or the deadline for meeting the unit’s monitor certification requirements under 40 CFR 97.370(b)(1), (2), (3) or (7) and for each control period thereafter. (3) A CAIR NOX allowance shall not be deducted, for compliance with the requirements under paragraph (c)(1) of this permit, for a control period in a calendar year before the year for which the CAIR NOX allowance was allocated. (4) CAIR NOX allowances shall be held in, deducted from, or transferred into or among CAIR NOX Allowance Tracking System accounts in accordance with subparts EEEE, FFFF, GGGG, or IIII of 40 CFR part 97. (5) A CAIR NOX Ozone Season allowance is a limited authorization to emit one ton of nitrogen oxides in accordance with the CAIR NOX Ozone Season Trading Program. No provision of the CAIR NOX Ozone Season Trading Program, the CAIR permit application, the CAIR permit, or an exemption under § 97.305 and no provision of law shall be construed to limit the authority of the United States to terminate or limit such authorization. (6) A CAIR NOX allowance does not constitute a property right. (7) Upon recordation by the Administrator under subpart EEEE, FFFF, GGGG, or IIII of 40 CFR part 97, every allocation, transfer, or deduction of a CAIR NOX allowance to or from a CAIR NOX source’s compliance account is incorporated automatically in any CAIR permit of the source. (d) Excess Emissions Requirements.




Page 93 of 93

If a CAIR NOX source emits nitrogen oxides during any control period in excess of the CAIR NOX emissions limitation, then: (1) The owners and operators of the source and each CAIR NOX unit at the source shall surrender the CAIR NOX allowances required for deduction under 40 CFR 97.354(d)(1) and pay any fine, penalty, or assessment or comply with any other remedy imposed, for the same violations, under the Clean Air Act or applicable State law; and (2) Each ton of such excess emissions and each day of such control period shall constitute a separate violation of 40 CFR part 97, the Clean Air Act, and applicable State rules. (e) Recordkeeping and Reporting Requirements. (1) Unless otherwise provided, the owners and operators of the CAIR NOX source and each CAIR NOX unit at the source shall keep on site at the source each of the following documents for a period of 5 years from the date the document is created. This period may be extended for cause, at any time before the end of 5 years, in writing by the MDEQ-AQD or the Administrator.

(i) The certificate of representation under § 97.313 for the CAIR designated representative for the source and each CAIR NOX unit at the source and all documents that demonstrate the truth of the statements in the certificate of representation; provided that the certificate and documents shall be retained on site at the source beyond such 5-year period until such documents are superseded because of the submission of a new certificate of representation under § 97.313 changing the CAIR designated representative.

(ii) All emissions monitoring information, in accordance with subpart HHHH of 40 CFR part 97.

(iii) Copies of all reports, compliance certifications, and other submissions and all records made or required under the CAIR NOX Ozone Trading Program.

(iv) Copies of all documents used to complete a CAIR permit application and any other submission under the CAIR NOX Ozone Trading Program or to demonstrate compliance with the requirements of the CAIR NOX Ozone Trading Program.

(2) The CAIR designated representative of a CAIR NOX source and each CAIR NOX unit at the source shall submit the reports required under the CAIR NOX Ozone Trading Program, including those under subpart HHHH of 40 CFR part 97. (f) Liability. (1) Each CAIR NOX source and each CAIR NOX unit shall meet the requirements of the CAIR NOX Ozone Trading Program. (2) Any provision of the CAIR NOX Ozone Trading Program that applies to a CAIR NOX source or the CAIR designated representative of a CAIR NOX source shall also apply to the owners and operators of such source and of the CAIR NOX units at the source. (3) Any provision of the CAIR NOX Ozone Trading Program that applies to a CAIR NOX unit or the CAIR designated representative of a CAIR NOX unit shall also apply to the owners and operators of such unit. (g) Effect on Other Authorities. No provision of the CAIR NOX Ozone Trading Program, a CAIR permit application, a CAIR permit, or an exemption under § 97.305 shall be construed as exempting or excluding the owners and operators, and the CAIR designated representative, of a CAIR NOX source or CAIR NOX unit from compliance with any other provision of the applicable, approved State implementation plan, a federally enforceable permit, or the Clean Air Act.

Appendix 2

March 1, 2013

Mr. Brian Warner

Wolverine Power Cooperative

10125 W. Watergate Road

P.O. Box 229

Cadillac, MI 49601

Re: Presque Isle Capacity Statement

Dear Mr. Warner:

This letter is to confirm that the intent of the Presque Isle Power Plant AQCS Retrofit Project is

to install air polluction control equipment to existing utility boilers which will allow the plant

to remain in compliance with current and near-future applicable air quality regulations. The

maximum capacity of each boiler will not increase as a result of this project. A more specific

description of the boiler modifications included within the project is as follows:

1. Part of the project is to replace the existing pulverized coal fired burners on boilers 5

and 6 with pulverized coal fired low NOX burners. These burners will reduce the

potential NOX emissions by design. These burners will maintain the current heat input

for each unit, and will not be sized to increase the capacity of each unit’s ability to

generate steam.

2. None of the steam turbines associated with each unit will be physically changed or

modified.

3. The combustion air fans will not be changed to accommodate a higher air flow rate that

could be used to increase the ability of each unit to burn more fuel.

4. The booster fans for drawing exhaust gases from each unit downstream of the induced

draft fans will be changed to accommodate increased pressure drop due to the additional

air quality control systems. Each fan will not be changed to accommodate a higher

exhaust gas flow rate that could potentially increase each unit’s capacity for steam

generation.

5. Other than replacing the coal fired burners, there will be no design changes to the

internal components of each unit to accommodate a higher thermal transfer of available

Mr. Brian Warner

Wolverine Power Cooperative

February 5, 2013

Page 2

heat from the combustion of fuel to the boiler water. Thus the steam properties will not

be changed that could potentially increase each unit’s capacity.

6. No design changes will be made to the coal processing and burner feed systems for each

unit to accommodate a higher design heat input rate. Nonetheless, even if changes to the

fuel feed systems were to be made, the combustion system (including the new burners)

will not be designed to accommodate a higher heat input rate. The burners would be a

bottleneck in the ability for each unit to combust fuel and generate steam.

7. Each unit has been operated in the recent past on a short-term basis at its design MCR.

Therefore, no changes are necessary to restore each unit’s ability to operate at its design

MCR.

Once again, none of the modifications associated with the project will increase the maximum

generating capacity of the boilers.

Sincerely,

Thomas R. Ghesquiere

Associate Vice President

Cc: Sharon Cameli, We Energies

Brad Smith, We Energies

Jackie Linck, FTCH

John Caudell, FTCH

Dave Ferrier, FTCH

Andy Sutherland, HDR

Appendix 3

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Appendix 3a - Past Heat Inputs

Unit 5 (MMBtu/month)





Total (MMBtu/month)

24 month rolling (MMBtu/year)

5 6 7 8 92008 4 433,577 588,634 - 680,382 696,679 2,399,272 1,199,636 2008 5 325,091 571,092 452,912 566,325 340,742 2,256,162 2,327,717 2008 6 516,832 547,064 588,990 602,190 514,271 2,769,348 3,712,391 2008 7 468,814 497,279 654,832 681,991 705,193 3,008,109 5,216,445 2008 8 580,813 594,870 626,313 638,776 629,264 3,070,037 6,751,464 2008 9 414,780 529,774 631,386 682,653 673,258 2,931,852 8,217,390 2008 10 186,929 409,570 653,733 635,579 711,146 2,596,955 9,515,867 2008 11 526,208 314,705 586,984 538,986 441,475 2,408,359 10,720,047 2008 12 551,826 575,144 490,239 638,535 - 2,255,744 11,847,919 2009 1 563,714 570,598 640,383 675,679 598,630 3,049,003 13,372,420 2009 2 437,051 434,745 567,808 569,411 606,140 2,615,154 14,679,998 2009 3 349,398 441,258 611,700 - 667,733 2,070,088 15,715,042 2009 4 442,791 442,914 110,592 532,912 595,460 2,124,670 16,777,377 2009 5 485,002 489,669 412,433 561,685 492,973 2,441,763 17,998,258 2009 6 529,025 448,892 586,956 629,558 633,246 2,827,677 19,412,097 2009 7 518,864 572,047 570,152 682,042 682,970 3,026,075 20,925,134 2009 8 439,841 590,129 496,807 635,339 607,617 2,769,734 22,310,001 2009 9 60,842 577,563 535,231 659,887 561,701 2,395,225 23,507,613 2009 10 90,498 456,390 642,831 694,601 579,215 2,463,535 24,739,381 2009 11 259,376 79,621 592,001 637,176 497,275 2,065,451 25,772,106 2009 12 519,280 215,507 460,940 509,332 633,082 2,338,141 26,941,177 2010 1 521,069 560,012 550,150 615,630 368,345 2,615,205 28,248,779 2010 2 408,799 490,066 589,997 274,593 567,526 2,330,981 29,414,270 2010 3 435,665 447,157 249,023 515,809 610,072 2,257,726 30,543,133 2010 4 367,364 320,711 170,226 599,028 591,246 2,048,575 30,367,784 2010 5 255,439 415,895 489,857 648,640 545,688 2,355,518 30,417,462 2010 6 330,310 135,922 594,395 636,106 639,113 2,335,846 30,200,711 2010 7 359,961 224,619 558,496 671,911 666,218 2,481,205 29,937,260 2010 8 325,757 470,203 590,683 632,329 571,815 2,590,787 29,697,635 2010 9 40,269 418,485 580,877 615,839 660,057 2,315,526 29,389,472 2010 10 490,824 141,771 579,054 688,278 683,939 2,583,865 29,382,927 2010 11 575,609 428,859 620,786 633,637 183,664 2,442,556 29,400,025 2010 12 580,824 598,665 596,125 683,501 - 2,459,115 29,501,710 2011 1 510,408 404,562 475,578 499,213 522,812 2,412,572 29,183,495 2011 2 149,068 363,570 561,737 602,689 598,383 2,275,447 29,013,641 2011 3 463,470 485,706 565,899 80,492 645,412 2,240,977 29,099,086 2011 4 391,304 300,969 553,145 388,797 591,245 2,225,461 29,149,481 2011 5 284,940 495,814 273,878 570,942 546,495 2,172,069 29,014,635 2011 6 384,631 300,134 576,208 613,204 550,502 2,424,680 28,813,136 2011 7 436,737 322,624 575,778 647,229 592,547 2,574,916 28,587,556 2011 8 237,255 476,481 529,468 595,254 591,492 2,429,950 28,417,664 2011 9 - 463,202 544,573 580,922 517,479 2,106,175 28,273,139 2011 10 - 407,622 511,840 640,171 603,185 2,162,818 28,122,781 2011 11 203,363 298,009 557,174 632,655 618,858 2,310,058 28,245,085 2011 12 426,928 356,575 552,232 540,195 196,547 2,072,478 28,112,253 2012 1 372,350 391,713 204,484 585,693 527,677 2,081,917 27,845,609 2012 2 368,169 389,244 521,425 76,022 557,687 1,912,547 27,636,392 2012 3 376,914 424,709 42,061 531,179 509,515 1,884,378 27,449,718 2012 4 335,265 404,903 - 525,356 522,563 1,788,087 27,319,474 2012 5 351,483 421,844 410,895 475,235 525,607 2,185,064 27,234,247 2012 6 343,493 252,542 64,623 417,683 425,765 1,504,106 26,818,377


Heat Input

Year Month

Z:\2012\120697\WORK\Rept\PTI Application\NEW_April_PIPP_Rolling_Avg_2013_0304.xlsx 3/7/2013

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Appendix 3a - Past Heat Inputs






Total (MMBtu/month)

24 month rolling (MMBtu/year)


Heat Input

Year Month2012 7 368,431 395,289 591,572 600,183 632,062 2,587,536 26,871,542 2012 8 197,995 353,190 547,989 388,774 113,418 1,601,366 26,376,831 2012 9 326,785 227,964 409,212 361,550 284,886 1,610,397 26,024,267 2012 10 412,415 - 528,929 615,869 607,263 2,164,476 25,814,572 2012 11 195,000 212,154 571,161 609,192 600,245 2,187,751 25,687,170 2012 12 - 344,076 557,537 495,229 592,737 1,989,579 25,452,402

580,824 598,665 654,832 694,601 711,146 3,240,067 MAX


of 1

Bituminous (tons)

Heat Content (Btu/lb)

Sulfur Content %

Ash Content %

Subbituminous (tons)


Sulfur Content %

Ash Content %

Fuel Oil (gals)

Bituminous (tons)


Sulfur Content %

Ash Content %



Sulfur Content %

Ash Content %

Fuel Oil (gals)



Sulfur Content %

Ash Content %

Reburn Ash (tons)

Fuel Oil (gals)



Sulfur Content %

Ash Content %

Reburn Ash (tons)

Fuel Oil (gals)



Sulfur Content %

Ash Content %

Reburn Ash (tons)

Fuel Oil (gals)

2008 4 19,625 11,904 0.46 9.68 16,003 25,084 11,906 0.46 9.68 5,414 0 - 0.00 0.0 0 0 37,950 9,057 0.27 4.69 0 0 36,601 9,057 0.27 4.69 0 02008 5 14,937 11,818 0.45 9.80 9,587 24,399 11,833 0.45 9.77 8,774 22,978 9,057 0.27 4.9 223 30,430 30,465 9,057 0.27 4.68 302 21,032 19,865 9,057 0.27 4.69 195 3,4592008 6 22,908 11,749 0.45 9.92 4,833 23,274 11,749 0.45 9.92 4,592 36,949 9,056 0.27 4.7 60 0 31,733 9,056 0.27 4.67 51 19,821 24,520 9,056 0.27 4.67 39 45,8262008 7 20,753 11,746 0.45 9.90 11,995 21,258 11,746 0.45 9.90 10,208 37,107 9,055 0.27 4.7 133 0 34,804 9,055 0.27 4.65 121 7,664 37,828 9,055 0.27 4.65 136 7,2372008 8 25,883 11,702 0.46 10.10 2,400 25,775 11,702 0.46 10.10 3,329 36,739 9,055 0.27 4.7 313 292 31,500 9,054 0.37 4.63 278 20,266 32,075 9,055 0.35 4.63 278 26,8002008 9 18,244 11,780 0.46 9.97 13,512 22,530 11,795 0.46 9.94 6,102 35,115 9,051 0.37 4.7 149 0 35,815 9,051 0.37 4.61 149 962 36,363 9,051 0.37 4.61 153 62008 10 7,785 11,983 0.47 9.32 16,428 16,392 11,925 0.47 9.51 10,225 37,857 9,049 0.32 4.8 263 2,241 32,169 9,049 0.32 4.60 225 14,621 38,279 9,049 0.32 4.60 263 02008 11 23,316 11,971 0.47 9.37 2,918 12,944 11,971 0.47 9.37 24,851 32,012 9,039 0.29 4.8 159 64,774 25,792 9,039 0.29 4.61 130 41,069 25,422 9,040 0.29 4.61 130 1,8262008 12 24,413 11,870 0.48 9.65 9,008 24,697 11,870 0.48 9.65 3,817 27,265 9035 0.28 4.6 0 40,425 32,524 9,035 0.28 4.61 0 26,925 0 - - - 0 02009 1 25,088 11,812 0.49 9.88 3,181 26,401 11,812 0.49 9.88 7,712 36,830 9,033 0.28 4.63 241.00 34,511 9,033 0.28 4.63 15,184 31,386 9,033 0.28 4.63 19,384.02009 2 19,479 11,812 0.49 9.89 3,844 20,193 11,812 0.49 9.89 3,416 32,617 9,033 0.28 4.63 28,340 9,033 0.28 4.63 8,782 32,995 9,033 0.28 4.63 10.02009 3 15,349 11,812 0.49 9.89 14,420 19,109 11,812 0.49 9.89 3,556 32,371 9,033 0.28 4.63 3,593 36,129 9,033 0.28 4.632009 4 19,620 11,769 0.48 9.77 2,937 19,411 11,768 0.48 9.77 2,437 4,856 9,031 0.27 4.61 21,840 26,526 9,031 0.27 4.61 17,069 34,540 9,031 0.27 4.61 276.02009 5 21,742 11,711 0.48 9.81 10,019 21,332 11,710 0.48 9.81 3,716 23,690 9,031 0.27 4.61 33,543 27,449 9,031 0.27 4.61 39,160 26,659 9,031 0.27 4.61 24,0032009 6 23,216 11,702 0.48 9.80 3,629 19,212 11,704 0.48 9.79 13,936 34,639 8,998 0.27 4.75 179.00 32,482 8,999 0.27 4.74 163.00 32,516 8,998 0.27 4.75 168.002009 7 23,302 11,662 0.48 9.82 4,871 24,617 11,662 0.48 9.82 4,117 34,288 8,976 0.27 4.85 238.00 1,362 34,802 8,977 0.27 4.85 238.00 35,202 8,976 0.27 4.85 245.002009 8 19,767 11,649 0.48 9.89 12,275 25,701 11,648 0.48 9.89 3,061 27,389 9,035 0.27 4.58 32,378 33,540 9,035 0.27 4.58 10,565 32,782 9,035 0.27 4.58 16,7492009 9 2,707 11,645 0.48 9.91 2,836 24,907 11,652 0.48 9.88 2,772 29,759 9,037 0.27 4.54 8,004 33,555 9,037 0.27 4.55 4,332 28,015 9,037 0.27 4.55 12,3932009 10 3,910 11,698 0.49 9.65 32,611 20,124 11,693 0.49 9.67 7,403 38,398 9,037 0.26 4.53 115 37,199 9,037 0.26 4.53 28,570 9,037 0.26 4.53 16,8322009 11 11,431 11,698 0.49 9.64 11,045 3,635 11,698 0.49 9.65 1,778 34,215 9,037 0.26 4.52 924 33,374 9,037 0.26 4.52 24,766 9,037 0.26 4.52 23,2272009 12 23,386 11,697 0.49 9.64 6,540 9,256 11,697 0.49 9.64 10,378 24,994 9,039 0.26 4.49 22,712 25,590 9,038 0.26 4.50 21,493 35,138 9,038 0.26 4.50 11.02010 1 23,687 11,697 0.49 9.64 2,644 24,643 11,697 0.49 9.64 2,562 30,588 9,039 0.26 4.49 9,072 32,725 9,039 0.26 4.49 6,755 19,570 9,039 0.26 4.49 14,3002010 2 18,427 11,697 0.49 9.64 6,637 21,686 11,697 0.49 9.64 1,346 34,697 9,039 0.26 4.49 1,086 13,845 9,039 0.26 4.49 1,658 29,136 9,039 0.26 4.49 7,4922010 3 19,621 11,697 0.49 9.64 9,496 20,033 11,697 0.49 9.64 3,150 14,891 9,039 0.26 4.49 2,931 26,000 9,039 0.27 4.48 21,777 34,065 9,039 0.27 4.48 18,1032010 4 16,286 11,716 0.48 9.62 7,941 14,330 11,709 0.49 9.63 13,788 5,655 9,037 0.30 4.48 30,372 33,781 9,038 0.31 4.48 8,377 34,500 9,038 0.31 4.48 9,1552010 5 10,802 11,754 0.47 9.55 2,642 17,962 11,754 0.47 9.55 8,121 26,963 9,023 0.28 4.51 45.00 18,409 36,188 9,023 0.28 4.51 60.00 27,701 9,023 0.28 4.51 45.00 20,2212010 6 13,759 11,756 0.47 9.54 2,987 5,940 11,763 0.47 9.53 195 32,044 9,021 0.27 4.50 47.00 3,475 34,933 9,020 0.27 4.50 53.00 114 33,924 9,020 0.27 4.50 51.002010 7 15,140 11,732 0.47 9.55 10,203 9,541 11,721 0.47 9.55 27,925 29,918 9,019 0.26 4.48 44.00 24,742 36,266 9,019 0.26 4.48 54.00 3,552 35,924 9,019 0.26 4.48 53.00 6,5142010 8 13,652 11,709 0.47 9.55 23,196 20,614 11,709 0.47 9.55 3,532 35,375 9,029 0.26 4.45 2,606 33,014 9,030 0.26 4.45 13,864 30,255 9,030 0.26 4.45 24,9052010 9 1,693 11,709 0.47 9.55 2,931 18,205 11,709 0.47 9.55 6,131 32,528 9,027 0.26 4.45 9,120 32,937 9,026 0.26 4.45 10,084 36,146 9,026 0.26 4.45 3,7242010 10 21,156 11,612 0.47 9.50 13,594 6,109 11,699 0.47 9.55 9,446 32,268 9,024 0.25 4.46 11,198 37,409 9,023 0.25 4.46 5,915 37,620 9,023 0.25 4.46 7,7122010 11 24,099 11,604 0.47 9.50 2,393 17,289 11,604 0.47 9.50 16,223 35,584 9,024 0.25 4.45 1,098 32,712 9,024 0.25 4.45 8,496 9,909 9,022 0.25 4.46 1,8252010 12 24,406 11,604 0.47 9.50 3,207 24,016 11,604 0.47 9.50 4,165 32,982 9,028 0.25 4.42 22,650 35,613 9,028 0.25 4.42 19,8102011 1 6,866 9,755 0.31 5.8 17,527 9,031 0.25 4.41 1,933 10,673 10,591 0.39 7.49 6,933.00 9,031.00 0.25 4.41 3,832 28,843 9,031 0.25 4.41 16,170 24,457 9,030 0.25 4.41 18,291 28,448 9,031.00 0.25 4.41 30,9302011 2 1,016 9,425 0.28 5.2 6,353 9,031 0.25 4.41 11,152 4,729 9,862 0.32 6.05 12,173.00 9,031.00 0.25 4.41 10,197 33,207 9,031 0.25 4.41 3,775 30,425 9,031 0.25 4.41 4,899 32,478 9,031 0.25 4.41 10.02011 3 19,348 11,605 0.47 9.5 7,920 19,522 11,604 0.47 9.50 1,649 32,061 9,033 0.25 4.41 12,124 4,238 9,031 0.25 4.41 1,344 32,779 9,033 0.25 4.41 14,7102011 4 17,032 11,625 0.47 9.5 7,772 12,143 11,621 0.47 9.48 7,511 30,409 9,035 0.25 4.40 12,564 18,091 9,035 0.25 4.40 37,027 35,673 9,035 0.25 4.40 242.02011 5 12,202 11,675 0.47 9.5 7,046 20,600 11,684 0.47 9.50 5,778 15,335 9,032 0.26 4.42 8,770 30,324 9,035 0.26 4.40 34,042 30,373 9,035 0.26 4.40 29,5992011 6 17,351 11,695 0.47 9.5 12,430 12,092 11,695 0.47 9.54 2,312 33,209 9,023 0.26 4.44 17,723 31,175 9,023 0.26 4.44 15,975 30,645 9,023 0.26 4.44 20,3652011 7 17,362 11,585 0.46 9.4 1,197 9,023 0.42 4.26 9,675 13,171 11,767 0.48 9.68 8,185 31,270 9,023 0.42 4.26 11,461 33,482 9,023 0.40 4.28 32,363 9,023 0.42 4.26 10,4012011 8 9,812 11,435 0.43 8.8 0 13,983 19,633 11,990 0.48 9.99 9,807 29,937 9,022 0.26 4.42 14,439 32,063 9,022 0.26 4.42 15,647 30,672 9,022 0.26 4.42 13,6782011 9 18,927 11,873 0.45 9.42 91 31,365 9,026 0.26 4.40 6,809 31,407 9,026 0.26 4.40 17,000 26,057 9,026 0.26 4.40 34,9482011 10 17,192 11,905 0.45 9.43 9,563 27,012 9,029 0.26 4.40 16,745 35,021 9,028 0.26 4.40 1,111 32,038 9,028 0.26 4.40 13,7962011 11 10,789 9,022 0.26 4.40 26,058 6,113 10,305 0.35 6.64 7,629 9,022 0.26 4.40 8,254 29,774 9,022 0.26 4.40 10,557 33,425 9,022 0.26 4.40 6,456 33,849 9,022 0.26 4.40 267.02011 12 23,164 9,017 0.26 4.41 5,328 9,017 0.26 4.41 19,365 9,017 0.26 4.41 13,952 31,834 9,017 0.26 4.41 17,028 27,174 9,017 0.26 4.41 35,558 10,565 9,018 0.26 4.41 3,1072012 1 19,936 9,019 0.26 4.35 10,006 20,785 9,019 0.26 4.35 11,262 9,462 9,018 0.26 4.35 21,932 32,863 9,019 0.26 4.35 2,919 27,671 9,019 0.26 4.35 21,7972012 2 19,730 9,020 0.26 4.41 17,036 20,679 9,020 0.26 4.41 8,353 29,761 9,020 0.26 4.41 3,606 1,428 9,020 0.26 4.41 10,584 30,170 9,020 0.26 4.41 3,6922012 3 20,666 9,017 0.26 4.41 7,776 22,827 9,016 0.26 4.41 1,941 2,169 9,020 0.26 4.41 2,623 30,245 9,016 0.26 4.41 3,488 25,310 9,016 0.26 4.41 27,6152012 4 17,923 9,005 0.26 4.42 7,956 21,097 9,005 0.26 4.42 5,934 1,723 0.10 4.42 27,945 9,005 0.26 4.42 14,010 27,303 9,005 0.26 4.42 3,7022012 5 18,936 9,005 0.26 4.41 16,306 22,592 9,005 0.26 4.41 3,863 20,450 9,005 0.26 4.41 25,883 27,115 9,005 0.26 4.41 11,938 27,779 9,005 0.26 4.41 2,3612012 6 19,215 9,010 0.26 4.41 6,743 13,667 9,010 0.26 4.41 8,710 2,755 9,011 0.26 4.41 9,652 23,624 9,011 0.26 4.41 18,813 22,376 9,011 0.26 4.41 39,9732012 7 20,476 9,012 0.26 4.41 9,468 21,062 9,012 0.26 4.41 16,126 33,465 9,012 0.26 4.41 42 31,370 9,012 0.26 4.41 11,676 33,049 9,012 0.26 4.41 53.02012 8 10,938 9,019 0.26 4.39 13,487 18,782 9,019 0.26 4.39 10,025 30,830 9,019 0.26 4.39 30 20,250 9,018 0.26 4.39 3,882 5,051 9,017 0.26 4.40 2,0392012 9 18,185 9,022 0.26 4.37 12,504 12,084 9,021 0.26 4.38 10,838 23,113 9,022 0.26 4.37 9,674 19,953 9,022 0.26 4.37 17,483 14,110 9,023 0.26 4.37 19,8052012 10 23,028 9,025 0.26 4.36 20,953 0 0.00 0.00 28,928 9,024 0.26 4.36 193 33,009 9,025 0.26 4.36 33,487 32,183 9,025 0.26 4.36 2,7452012 11 10,843 9,026 0.26 4.36 7,073 11,198 9,029 0.26 4.36 8,554 30,928 9,028 0.26 4.36 11,028 32,576 9,028 0.26 4.36 1.0 31,093 9,028 0.26 4.362012 12

Boiler 6 Boiler 7 Boiler 8 Boiler 9

Appendix 3b - Past Fuel UsageAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Year Month

Boiler 5


of 1

Year Month

Unit 5NOx

(tons/month)

Unit 6NOx

(tons/month)

Unit 7NOx

(tons/month)

Unit 8NOx

(tons/month)

Unit 9NOx

(tons/month)Total NOx

(tons/month)

Total NOx 24-month

rolling (tpy)

2008 4 72.8 109.9 0.00 137.5 141.0 461.1 230.52008 5 59.9 102.4 89.15 112.3 67.9 431.6 446.42008 6 102.0 102.5 118.25 122.6 106.0 551.4 7222008 7 92.9 95.1 133.95 139.0 145.0 605.9 1,0252008 8 112.4 118.1 126.52 129.4 127.1 613.4 1,3322008 9 75.79 105.05 130.03 138.6 139.4 588.9 1,6262008 10 36.45 76.79 130.64 127.9 141.4 513.2 1,8832008 11 100.3 57.73 112.79 105.1 86.3 462.1 2,1142008 12 101.4 110.41 92.44 122.0 0.0 426.2 2,3272009 1 107.3 110.19 122.51 127.7 111.9 579.6 2,6172009 2 78.33 79.52 110.56 108.6 116.8 493.8 2,8642009 3 62.60 77.39 120.13 0.0 131.0 391.1 3,0592009 4 76.03 76.64 21.29 101.6 113.4 389.0 3,2542009 5 89.55 89.43 77.86 106.9 93.0 456.7 3,4822009 6 106.52 85.10 111.80 121.0 119.1 543.6 3,7542009 7 99.22 108.77 108.81 131.2 129.1 577.1 4,0422009 8 85.27 118.33 96.67 123.7 117.6 541.6 4,3132009 9 9.37 112.04 101.74 124.0 105.3 452.5 4,5392009 10 15.82 92.15 126.94 137.4 116.6 489.0 4,7842009 11 51.79 15.15 115.72 124.1 97.5 404.2 4,9862009 12 104.90 42.09 89.30 98.5 123.3 458.1 5,2152010 1 102.38 115.76 107.61 120.8 71.6 518.1 5,4742010 2 79.85 96.97 115.68 53.5 112.6 458.7 5,7032010 3 76.99 81.87 49.29 102.2 122.0 432.4 5,9202010 4 62.30 56.10 33.90 118.7 117.5 388.5 5,8832010 5 41.58 74.92 96.52 129.9 110.9 453.8 5,8942010 6 58.76 26.14 116.77 127.2 129.1 457.9 5,8482010 7 66.60 42.94 112.50 135.7 133.7 491.4 5,7912010 8 59.58 88.73 119.31 128.3 113.6 509.4 5,7392010 9 7.13 76.83 116.91 126.0 134.0 460.9 5,6752010 10 97.95 27.11 116.76 138.2 136.1 516.1 5,6762010 11 115.86 82.98 126.46 127.4 37.2 489.9 5,6902010 12 117.76 118.01 123.04 138.5 0.0 497.3 5,7252011 1 89.26 74.07 97.59 99.7 103.2 463.8 5,6682011 2 23.05 61.24 113.51 118.7 117.5 434.1 5,6382011 3 82.75 89.03 114.45 15.9 128.0 430.2 5,6572011 4 61.34 47.87 110.36 75.4 115.9 410.9 5,6682011 5 50.87 92.84 54.82 113.8 108.0 420.4 5,6502011 6 65.27 55.42 113.53 121.8 108.6 464.6 5,6112011 7 84.81 58.78 112.23 127.6 116.8 500.2 5,5722011 8 40.97 84.88 104.79 116.5 115.5 462.7 5,5332011 9 0.00 75.88 104.23 109.6 97.0 386.7 5,5002011 10 0.00 68.71 89.13 109.2 103.4 370.5 5,4402011 11 31.31 50.67 93.88 103.3 102.3 381.4 5,4292011 12 58.73 56.21 94.93 89.09 31.93 330.9 5,3652012 1 51.24 56.69 33.83 94.34 85.37 321.5 5,2672012 2 53.33 57.54 87.33 12.40 90.77 301.4 5,1882012 3 58.21 64.86 7.26 82.86 80.34 293.5 5,1192012 4 51.96 61.55 0.00 80.44 81.70 275.7 5,0632012 5 52.72 67.37 67.41 77.00 84.11 348.6 5,0102012 6 50.84 44.36 10.98 68.23 69.49 243.9 4,9032012 7 54.90 63.61 100.09 99.18 105.21 423.0 4,8692012 8 28.94 48.70 85.68 59.48 17.85 240.7 4,7342012 9 44.42 31.01 68.57 59.82 46.80 250.6 4,6292012 10 56.80 0.00 89.43 99.29 100.83 346.4 4,5442012 11 26.46 27.86 94.88 96.05 98.37 343.6 4,4712012 12 0.00 43.35 91.06 76.81 95.03 306.3 4,376

Appendix 3c – NOX Emissions



of 1

PM Fuel Oil (tons/month)

PM Filterable - Coal

(tons/month)PM Total

(tons/month)PM Fuel Oil (tons/month)


(tons/month)

PM Total (tons/month

)PM Fuel Oil (tons/month)



(tons/month)PM Fuel Oil (tons/month)


(tons/month)

PM Total (tons/month

)PM Fuel Oil (tons/month)



(tons/month)Emission Factor 2 0.0044 2 0.0044 2 0.007 2 0.007 2 0.0073Emission Factor Units lb/kgal lb/MMBtu lb/kgal lb/MMBtu lb/kgal lb/MMBtu lb/kgal lb/MMBtu lb/kgal lb/MMBtuControl Efficiency 99.89% 99.89% 99.89% 99.89% 99.89%

2008 4 42008 1.760E-05 1.028 1.028 5.955E-06 1.314 1.314 0.000E+00 0.0000 0.0000 0.000E+00 2.406 2.406 0.000E+00 2.420 2.420 7.168 3.58 420082008 5 52008 1.055E-05 0.777 0.777 9.651E-06 1.270 1.270 3.347E-05 1.4709 1.4709 2.314E-05 1.951 1.951 3.805E-06 1.326 1.326 6.795 6.98 520082008 6 62008 5.316E-06 1.184 1.184 5.051E-06 1.203 1.203 0.000E+00 2.3460 2.3460 2.180E-05 2.015 2.015 5.041E-05 1.624 1.624 8.372 11.17 620082008 7 72008 1.319E-05 1.073 1.073 1.123E-05 1.099 1.099 0.000E+00 2.3604 2.3604 8.430E-06 2.214 2.214 7.961E-06 2.509 2.509 9.255 15.79 720082008 8 82008 2.640E-06 1.333 1.333 3.662E-06 1.327 1.327 3.212E-07 2.3484 2.3484 2.229E-05 2.014 2.014 2.948E-05 2.138 2.139 9.161 20.37 820082008 9 92008 1.486E-05 0.946 0.946 6.712E-06 1.169 1.169 0.000E+00 2.2343 2.2343 1.058E-06 2.279 2.279 6.600E-09 2.413 2.413 9.041 24.90 920082008 10 102008 1.807E-05 0.410 0.410 1.125E-05 0.860 0.860 2.465E-06 2.4147 2.4147 1.608E-05 2.052 2.052 0.000E+00 2.546 2.546 8.283 29.04 1020082008 11 112008 3.210E-06 1.228 1.228 2.734E-05 0.682 0.682 7.125E-05 2.0355 2.0356 4.518E-05 1.640 1.640 2.009E-06 1.686 1.686 7.272 32.67 1120082008 12 122008 9.909E-06 1.275 1.275 4.199E-06 1.290 1.290 4.447E-05 1.7244 1.7244 2.962E-05 2.057 2.057 0.000E+00 0.000 0.000 6.346 35.85 1220082009 1 12009 3.499E-06 1.304 1.304 8.483E-06 1.372 1.372 2.651E-07 2.3288 2.3288 1.670E-05 2.182 2.182 2.132E-05 2.070 2.070 9.257 40.47 120092009 2 22009 4.228E-06 1.012 1.012 3.758E-06 1.049 1.049 0.000E+00 2.0624 2.0624 9.660E-06 1.792 1.792 1.100E-08 2.176 2.176 8.092 44.52 220092009 3 32009 1.586E-05 0.798 0.798 3.912E-06 0.993 0.993 3.952E-06 2.0469 2.0469 0.000E+00 0.000 0.000 0.000E+00 2.382 2.382 6.220 47.63 320092009 4 42009 3.231E-06 1.016 1.016 2.681E-06 1.005 1.005 2.402E-05 0.3070 0.3070 1.878E-05 1.677 1.677 3.036E-07 2.277 2.277 6.282 50.77 420092009 5 52009 1.102E-05 1.120 1.120 4.088E-06 1.099 1.099 3.690E-05 1.4976 1.4976 4.308E-05 1.735 1.735 2.640E-05 1.758 1.758 7.210 54.38 520092009 6 62009 3.992E-06 1.195 1.195 1.533E-05 0.989 0.989 0.000E+00 2.1930 2.1930 0.000E+00 2.056 2.056 0.000E+00 2.147 2.147 8.581 58.67 620092009 7 72009 5.358E-06 1.196 1.196 4.529E-06 1.263 1.263 1.498E-06 2.1693 2.1693 0.000E+00 2.202 2.202 0.000E+00 2.323 2.323 9.153 63.24 720092009 8 82009 1.350E-05 1.013 1.013 3.367E-06 1.317 1.317 3.562E-05 1.7322 1.7323 1.162E-05 2.121 2.121 1.842E-05 2.162 2.162 8.346 67.42 820092009 9 92009 3.120E-06 0.139 0.139 3.049E-06 1.277 1.277 8.804E-06 1.8825 1.8825 4.765E-06 2.123 2.123 1.363E-05 1.848 1.848 7.269 71.05 920092009 10 102009 3.587E-05 0.201 0.201 8.143E-06 1.035 1.035 1.265E-07 2.4290 2.4290 0.000E+00 2.353 2.353 1.852E-05 1.885 1.885 7.904 75.00 1020092009 11 112009 1.215E-05 0.588 0.588 1.956E-06 0.187 0.187 1.016E-06 2.1644 2.1644 0.000E+00 2.111 2.111 2.555E-05 1.634 1.634 6.685 78.35 1120092009 12 122009 7.194E-06 1.204 1.204 1.142E-05 0.476 0.476 2.498E-05 1.5814 1.5815 2.364E-05 1.619 1.619 1.210E-08 2.318 2.318 7.199 81.94 1220092010 1 12010 2.908E-06 1.219 1.219 2.818E-06 1.268 1.268 9.979E-06 1.9354 1.9354 7.430E-06 2.071 2.071 1.573E-05 1.291 1.291 7.785 85.84 120102010 2 22010 7.301E-06 0.948 0.948 1.481E-06 1.116 1.116 1.195E-06 2.1954 2.1954 1.824E-06 0.876 0.876 8.241E-06 1.923 1.923 7.058 89.37 220102010 3 32010 1.045E-05 1.010 1.010 3.465E-06 1.031 1.031 3.224E-06 0.9422 0.9422 2.395E-05 1.645 1.645 1.991E-05 2.248 2.248 6.876 92.80 320102010 4 42010 8.735E-06 0.840 0.840 1.517E-05 0.738 0.738 3.341E-05 0.3577 0.3578 9.215E-06 2.137 2.137 1.007E-05 2.276 2.276 6.349 92.39 420102010 5 52010 2.906E-06 0.559 0.559 8.933E-06 0.929 0.929 2.025E-05 1.7059 1.7059 0.000E+00 2.289 2.289 2.224E-05 1.828 1.828 7.311 92.65 520102010 6 62010 3.286E-06 0.712 0.712 2.145E-07 0.307 0.307 3.822E-06 2.0265 2.0265 1.254E-07 2.209 2.209 0.000E+00 2.237 2.237 7.492 92.21 620102010 7 72010 1.122E-05 0.782 0.782 3.072E-05 0.492 0.492 2.722E-05 1.8916 1.8916 3.907E-06 2.293 2.293 7.165E-06 2.369 2.369 7.827 91.50 720102010 8 82010 2.552E-05 0.703 0.703 3.885E-06 1.062 1.062 2.867E-06 2.2358 2.2358 1.525E-05 2.087 2.087 2.740E-05 1.994 1.994 8.082 90.96 820102010 9 92010 3.224E-06 0.087 0.087 6.744E-06 0.938 0.938 1.003E-05 2.0554 2.0554 1.109E-05 2.081 2.081 4.096E-06 2.382 2.382 7.543 90.21 920102010 10 102010 1.495E-05 1.081 1.081 1.039E-05 0.314 0.314 1.232E-05 2.0383 2.0383 6.506E-06 2.363 2.363 8.483E-06 2.478 2.478 8.274 90.21 1020102010 11 112010 2.632E-06 1.230 1.230 1.785E-05 0.883 0.883 1.208E-06 2.2478 2.2478 9.346E-06 2.066 2.066 2.007E-06 0.653 0.653 7.080 90.11 1120102010 12 122010 3.528E-06 1.246 1.246 4.581E-06 1.226 1.226 2.491E-05 2.0843 2.0844 2.179E-05 2.251 2.251 0.000E+00 0.000 0.000 6.807 90.34 1220102011 1 12011 2.126E-06 0.991 0.991 4.215E-06 0.773 0.773 1.779E-05 1.8234 1.8234 2.012E-05 1.546 1.546 3.402E-05 1.875 1.876 7.009 89.22 120112011 2 22011 1.227E-05 0.295 0.295 1.122E-05 0.689 0.689 4.152E-06 2.0992 2.0993 5.389E-06 1.923 1.923 1.100E-08 2.141 2.141 7.147 88.74 220112011 3 32011 8.712E-06 0.988 0.988 1.814E-06 0.997 0.997 1.334E-05 2.0272 2.0273 1.478E-06 0.268 0.268 1.618E-05 2.161 2.161 6.441 88.86 320112011 4 42011 8.549E-06 0.871 0.871 8.262E-06 0.621 0.621 1.382E-05 1.9232 1.9232 4.073E-05 1.144 1.144 2.662E-07 2.353 2.353 6.912 89.17 420112011 5 52011 7.751E-06 0.627 0.627 6.356E-06 1.059 1.059 9.647E-06 0.9695 0.9695 3.745E-05 1.918 1.918 3.256E-05 2.003 2.003 6.577 88.85 520112011 6 62011 1.367E-05 0.893 0.893 2.543E-06 0.622 0.622 1.950E-05 2.0975 2.0975 1.757E-05 1.969 1.969 2.240E-05 2.019 2.019 7.600 88.36 620112011 7 72011 1.064E-05 0.933 0.933 9.003E-06 0.682 0.682 1.261E-05 1.9750 1.9751 0.000E+00 2.115 2.115 1.144E-05 2.132 2.132 7.836 87.71 720112011 8 82011 1.538E-05 0.494 0.494 1.079E-05 1.036 1.036 1.588E-05 1.8906 1.8907 1.721E-05 2.025 2.025 1.505E-05 2.020 2.020 7.465 87.26 820112011 9 92011 0.000E+00 0.000 0.000 1.001E-07 0.989 0.989 7.490E-06 1.9817 1.9817 1.870E-05 1.984 1.984 3.844E-05 1.717 1.717 6.672 86.97 920112011 10 102011 0.000E+00 0.000 0.000 1.052E-05 0.901 0.901 1.842E-05 1.7072 1.7073 1.222E-06 2.213 2.213 1.518E-05 2.111 2.111 6.932 86.48 1020112011 11 112011 2.866E-05 0.428 0.428 9.079E-06 0.580 0.580 1.161E-05 1.8803 1.8804 7.102E-06 2.111 2.111 2.937E-07 2.229 2.229 7.229 86.75 1120112011 12 122011 5.861E-06 0.919 0.919 1.535E-05 0.768 0.768 1.873E-05 2.0093 2.0093 3.911E-05 1.715 1.715 3.418E-06 0.696 0.696 6.107 86.21 1220112012 1 12012 1.101E-05 0.791 0.791 1.239E-05 0.825 0.825 2.413E-05 0.5973 0.5973 3.211E-06 2.075 2.075 2.398E-05 1.822 1.822 6.110 85.37 120122012 2 22012 1.874E-05 0.783 0.783 9.188E-06 0.821 0.821 3.967E-06 1.8791 1.8791 1.164E-05 0.090 0.090 4.061E-06 1.987 1.987 5.560 84.62 220122012 3 32012 8.554E-06 0.820 0.820 2.135E-06 0.906 0.906 2.885E-06 0.1370 0.1370 3.837E-06 1.909 1.909 3.038E-05 1.666 1.666 5.437 83.90 320122012 4 42012 8.752E-06 0.710 0.710 6.527E-06 0.836 0.836 0.000E+00 0.0000 0.0000 1.541E-05 1.762 1.762 4.072E-06 1.795 1.795 5.102 83.28 420122012 5 52012 1.794E-05 0.750 0.750 4.249E-06 0.895 0.895 2.847E-05 1.2891 1.2891 1.313E-05 1.709 1.709 2.597E-06 1.826 1.826 6.470 82.86 520122012 6 62012 7.417E-06 0.762 0.762 9.581E-06 0.542 0.542 1.062E-05 0.1738 0.1738 2.069E-05 1.490 1.490 4.397E-05 1.472 1.472 4.439 81.33 620122012 7 72012 1.041E-05 0.812 0.812 1.774E-05 0.835 0.835 4.620E-08 2.1111 2.1111 1.284E-05 1.979 1.979 5.830E-08 2.174 2.174 7.911 81.37 720122012 8 82012 1.484E-05 0.434 0.434 1.103E-05 0.745 0.745 3.300E-08 1.9464 1.9464 4.270E-06 1.278 1.278 2.243E-06 0.332 0.332 4.737 79.70 820122012 9 92012 1.375E-05 0.722 0.722 1.192E-05 0.480 0.480 1.064E-05 1.4597 1.4597 1.923E-05 1.260 1.260 2.179E-05 0.929 0.929 4.851 78.35 920122012 10 102012 2.305E-05 0.914 0.914 0.000E+00 0.000 0.000 2.123E-07 1.8273 1.8273 3.684E-05 2.085 2.085 3.019E-06 2.120 2.120 6.947 77.69 1020122012 11 112012 7.780E-06 0.431 0.431 9.409E-06 0.445 0.445 1.213E-05 1.9545 1.9545 1.100E-09 2.059 2.059 0.000E+00 2.049 2.049 6.938 77.62 1120122012 12 122012 0.000E+00 0.000 0.000 0.000E+00 0.000 0.000 0.000E+00 0.0000 0.0000 0.000E+00 0.000 0.000 0.000E+00 0.000 0.000 0.000 74.22 122012

Appendix 3d – Past Actual PM Emissions


Unit 5 Unit 6 Unit 7 Unit 8 Unit 9

Total PM (tons/month)

Total PM 24-month

Rolling (tpy)

Month/ Year


of 1

PM10 Fuel Oil

(tons/month)

PM10 Filterable -

Coal (tons/month)

PM10 Condensible -

Coal (tons/month)

PM10 Total (tons/month)

PM10 Fuel Oil

(tons/month)

PM10 Filterable -

Coal (tons/month)

PM10 Condensible

- Coal (tons/month)


PM10 Fuel Oil (tons/month)

PM10 Filterable -

Coal (tons/month)

PM10 Condensible -

Coal (tons/month)


PM10 Fuel Oil (tons/month)

PM10 Filterable -

Coal (tons/month)

PM10 Condensible -

Coal (tons/month)

PM10 Total (tons/month

)

PM10 Fuel Oil

(tons/month)

PM10 Filterable -

Coal (tons/month)

PM10 Condensible -

Coal (tons/month)


Emission Factor 2.3 0.0044 0.01 2.3 0.0044 0.01 2.3 0.007 0.01 2.3 0.007 0.01 2.3 0.0073 0.01Emission Factor Units lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtuControl Efficiency 99.89% 99.89% 99.89% 99.89% 99.89%2008 4 42008 2.024E-05 1.028 3.683 4.711 6.849E-06 1.314 4.726 6.040 0.000E+00 0.000 0.000 0.000 0.000E+00 2.406 3.437 5.843 0.000E+00 2.420 3.315 5.735 22.33 11.16 420082008 5 52008 1.213E-05 0.777 2.660 3.437 1.110E-05 1.270 4.357 5.628 3.849E-05 1.471 2.101 3.572 2.661E-05 1.951 2.786 4.737 4.376E-06 1.326 1.817 3.143 20.52 21.42 520082008 6 62008 6.114E-06 1.184 4.016 5.201 5.809E-06 1.203 4.081 5.284 0.000E+00 2.346 3.351 5.698 2.507E-05 2.015 2.878 4.893 5.797E-05 1.624 2.224 3.848 24.92 33.88 620082008 7 72008 1.517E-05 1.073 3.719 4.792 1.291E-05 1.099 3.809 4.908 0.000E+00 2.360 3.372 5.733 9.695E-06 2.214 3.162 5.376 9.155E-06 2.509 3.438 5.947 26.76 47.26 720082008 8 82008 3.036E-06 1.333 4.839 6.172 4.211E-06 1.327 4.819 6.146 3.694E-07 2.348 3.355 5.703 2.564E-05 2.014 2.877 4.891 3.390E-05 2.138 2.929 5.068 27.98 61.25 820082008 9 92008 1.709E-05 0.946 3.505 4.450 7.719E-06 1.169 4.341 5.511 0.000E+00 2.234 3.192 5.426 1.217E-06 2.279 3.255 5.534 7.590E-09 2.413 3.305 5.718 26.64 74.57 920082008 10 102008 2.078E-05 0.410 1.575 1.985 1.293E-05 0.860 3.245 4.106 2.835E-06 2.415 3.450 5.864 1.850E-05 2.052 2.931 4.983 0.000E+00 2.546 3.488 6.034 22.97 86.06 1020082008 11 112008 3.691E-06 1.228 4.772 6.000 3.144E-05 0.682 2.656 3.338 8.194E-05 2.035 2.908 4.943 5.195E-05 1.640 2.343 3.983 2.310E-06 1.686 2.310 3.996 22.26 97.19 1120082008 12 122008 1.140E-05 1.275 5.119 6.394 4.829E-06 1.290 5.179 6.469 5.114E-05 1.724 2.463 4.188 3.406E-05 2.057 2.939 4.996 0.000E+00 0.000 0.000 0.000 22.05 108.2 1220082009 1 12009 4.024E-06 1.304 5.630 6.934 9.756E-06 1.372 5.925 7.297 3.049E-07 2.329 3.327 5.656 1.921E-05 2.182 3.117 5.300 2.452E-05 2.070 2.835 4.905 30.09 123.3 120092009 2 22009 4.863E-06 1.012 4.372 5.384 4.321E-06 1.049 4.532 5.581 0.000E+00 2.062 2.946 5.009 1.111E-05 1.792 2.560 4.352 1.265E-08 2.176 2.980 5.156 25.48 136.0 220092009 3 32009 1.824E-05 0.798 3.445 4.242 4.498E-06 0.993 4.289 5.282 4.545E-06 2.047 2.924 4.971 0.000E+00 0.000 0.000 0.000 0.000E+00 2.382 3.264 5.646 20.14 146.1 320092009 4 42009 3.715E-06 1.016 4.156 5.172 3.083E-06 1.005 4.112 5.117 2.763E-05 0.307 0.439 0.746 2.159E-05 1.677 2.396 4.072 3.491E-07 2.277 3.119 5.396 20.50 156.3 420092009 5 52009 1.267E-05 1.120 4.583 5.704 4.701E-06 1.099 4.496 5.595 4.243E-05 1.498 2.139 3.637 4.954E-05 1.735 2.479 4.214 3.036E-05 1.758 2.408 4.165 23.32 168.0 520092009 6 62009 4.591E-06 1.195 4.890 6.085 1.763E-05 0.989 4.047 5.037 0.000E+00 2.193 3.133 5.326 0.000E+00 2.056 2.938 4.994 0.000E+00 2.147 2.941 5.088 26.53 181.2 620092009 7 72009 6.162E-06 1.196 4.891 6.087 5.208E-06 1.263 5.168 6.431 1.723E-06 2.169 3.099 5.268 0.000E+00 2.202 3.146 5.347 0.000E+00 2.323 3.182 5.504 28.64 195.6 720092009 8 82009 1.553E-05 1.013 4.145 5.158 3.872E-06 1.317 5.389 6.706 4.096E-05 1.732 2.475 4.207 1.336E-05 2.121 3.030 5.152 2.119E-05 2.162 2.962 5.124 26.35 208.7 820092009 9 92009 3.588E-06 0.139 0.567 0.706 3.507E-06 1.277 5.224 6.501 1.013E-05 1.883 2.689 4.572 5.480E-06 2.123 3.032 5.155 1.568E-05 1.848 2.532 4.380 21.31 219.4 920092009 10 102009 4.125E-05 0.201 0.869 1.070 9.365E-06 1.035 4.471 5.506 1.455E-07 2.429 3.470 5.899 0.000E+00 2.353 3.362 5.715 2.129E-05 1.885 2.582 4.467 22.66 230.7 1020092009 11 112009 1.397E-05 0.588 2.541 3.129 2.249E-06 0.187 0.808 0.995 1.169E-06 2.164 3.092 5.256 0.000E+00 2.111 3.016 5.127 2.938E-05 1.634 2.238 3.872 18.38 239.9 1120092009 12 122009 8.273E-06 1.204 5.197 6.401 1.313E-05 0.476 2.057 2.533 2.873E-05 1.581 2.259 3.841 2.719E-05 1.619 2.313 3.932 1.391E-08 2.318 3.176 5.494 22.20 251.0 1220092010 1 12010 3.345E-06 1.219 5.264 6.483 3.241E-06 1.268 5.477 6.745 1.148E-05 1.935 2.765 4.700 8.545E-06 2.071 2.958 5.029 1.809E-05 1.291 1.769 3.060 26.02 264.0 120102010 2 22010 8.396E-06 0.948 4.095 5.044 1.703E-06 1.116 4.820 5.936 1.374E-06 2.195 3.136 5.332 2.097E-06 0.876 1.251 2.127 9.477E-06 1.923 2.634 4.556 22.99 275.5 220102010 3 32010 1.201E-05 1.010 4.361 5.370 3.985E-06 1.031 4.452 5.483 3.708E-06 0.942 1.346 2.288 2.755E-05 1.645 2.350 3.995 2.290E-05 2.248 3.079 5.327 22.46 286.7 320102010 4 42010 1.005E-05 0.840 3.435 4.274 1.744E-05 0.738 3.188 3.926 3.842E-05 0.358 0.511 0.869 1.060E-05 2.137 3.053 5.190 1.158E-05 2.276 3.118 5.394 19.65 285.4 420102010 5 52010 3.342E-06 0.559 2.158 2.717 1.027E-05 0.929 3.589 4.518 2.329E-05 1.706 2.437 4.143 0.000E+00 2.289 3.271 5.560 2.558E-05 1.828 2.504 4.331 21.27 285.8 520102010 6 62010 3.779E-06 0.712 2.750 3.461 2.467E-07 0.307 1.188 1.495 4.396E-06 2.026 2.895 4.921 1.442E-07 2.209 3.156 5.365 0.000E+00 2.237 3.065 5.302 20.54 283.6 620102010 7 72010 1.291E-05 0.782 3.020 3.801 3.533E-05 0.492 1.901 2.393 3.130E-05 1.892 2.702 4.594 4.493E-06 2.293 3.276 5.569 8.240E-06 2.369 3.245 5.613 21.97 281.2 720102010 8 82010 2.934E-05 0.703 2.717 3.421 4.468E-06 1.062 4.103 5.165 3.297E-06 2.236 3.194 5.430 1.754E-05 2.087 2.981 5.068 3.150E-05 1.994 2.732 4.726 23.81 279.1 820102010 9 92010 3.708E-06 0.087 0.337 0.424 7.756E-06 0.938 3.624 4.562 1.154E-05 2.055 2.936 4.992 1.276E-05 2.081 2.973 5.054 4.711E-06 2.382 3.263 5.644 20.68 276.1 920102010 10 102010 1.720E-05 1.081 4.176 5.257 1.195E-05 0.314 1.215 1.529 1.417E-05 2.038 2.912 4.950 7.482E-06 2.363 3.375 5.738 9.756E-06 2.478 3.394 5.872 23.35 276.3 1020102010 11 112010 3.027E-06 1.230 4.754 5.984 2.052E-05 0.883 3.411 4.293 1.389E-06 2.248 3.211 5.459 1.075E-05 2.066 2.952 5.018 2.309E-06 0.653 0.894 1.547 22.30 276.3 1120102010 12 122010 4.057E-06 1.246 4.815 6.061 5.269E-06 1.226 4.738 5.964 2.865E-05 2.084 2.978 5.062 2.506E-05 2.251 3.215 5.466 0.000E+00 0.000 0.000 0.000 22.55 276.6 1220102011 1 12011 2.445E-06 0.991 2.253 3.244 4.847E-06 0.773 1.756 2.529 2.046E-05 1.823 2.605 4.428 2.314E-05 1.546 2.208 3.754 3.913E-05 1.875 2.569 4.445 18.40 270.8 120112011 2 22011 1.411E-05 0.295 0.669 0.964 1.290E-05 0.689 1.566 2.255 4.775E-06 2.099 2.999 5.098 6.197E-06 1.923 2.748 4.671 1.265E-08 2.141 2.933 5.074 18.06 267.0 220112011 3 32011 1.002E-05 0.988 3.817 4.805 2.086E-06 0.997 3.851 4.848 1.534E-05 2.027 2.896 4.923 1.700E-06 0.268 0.383 0.651 1.861E-05 2.161 2.961 5.122 20.35 267.1 320112011 4 42011 9.832E-06 0.871 3.366 4.237 9.501E-06 0.621 2.399 3.020 1.589E-05 1.923 2.747 4.671 4.684E-05 1.144 1.635 2.779 3.061E-07 2.353 3.223 5.576 20.28 267.0 420112011 5 52011 8.913E-06 0.627 2.422 3.049 7.309E-06 1.059 4.092 5.151 1.109E-05 0.970 1.385 2.355 4.306E-05 1.918 2.740 4.658 3.744E-05 2.003 2.744 4.748 19.96 265.4 520112011 6 62011 1.572E-05 0.893 3.450 4.343 2.925E-06 0.622 2.404 3.026 2.242E-05 2.098 2.996 5.094 2.021E-05 1.969 2.813 4.782 2.576E-05 2.019 2.765 4.784 22.03 263.1 620112011 7 72011 1.224E-05 0.933 3.348 4.280 1.035E-05 0.682 2.790 3.472 1.450E-05 1.975 3.386 5.361 0.000E+00 2.115 3.021 5.136 1.316E-05 2.132 3.504 5.636 23.88 260.7 720112011 8 82011 1.769E-05 0.494 1.459 1.952 1.241E-05 1.036 4.237 5.273 1.827E-05 1.891 2.701 4.592 1.979E-05 2.025 2.893 4.918 1.730E-05 2.020 2.767 4.787 21.52 258.3 820112011 9 92011 0.000E+00 0.000 0.000 0.000 1.151E-07 0.989 3.371 4.360 8.613E-06 1.982 2.831 4.813 2.150E-05 1.984 2.835 4.819 4.421E-05 1.717 2.352 4.069 18.06 256.7 920112011 10 102011 0.000E+00 0.000 0.000 0.000 1.210E-05 0.901 3.070 3.971 2.118E-05 1.707 2.439 4.146 1.405E-06 2.213 3.162 5.375 1.745E-05 2.111 2.892 5.004 18.50 254.6 1020112011 11 112011 3.296E-05 0.428 0.973 1.402 1.044E-05 0.580 1.318 1.898 1.335E-05 1.880 2.686 4.567 8.167E-06 2.111 3.016 5.127 3.378E-07 2.229 3.054 5.283 18.28 254.6 1120112011 12 122011 6.740E-06 0.919 2.089 3.008 1.765E-05 0.768 1.746 2.514 2.154E-05 2.009 2.870 4.880 4.498E-05 1.715 2.450 4.166 3.930E-06 0.696 0.953 1.648 16.22 251.6 1220112012 1 12012 1.266E-05 0.791 1.798 2.589 1.425E-05 0.825 1.875 2.699 2.774E-05 0.597 0.853 1.451 3.693E-06 2.075 2.964 5.039 2.757E-05 1.822 2.496 4.317 16.10 246.6 120122012 2 22012 2.155E-05 0.783 1.780 2.563 1.057E-05 0.821 1.865 2.686 4.562E-06 1.879 2.684 4.564 1.339E-05 0.090 0.129 0.219 4.670E-06 1.987 2.721 4.708 14.74 242.5 220122012 3 32012 9.837E-06 0.820 1.863 2.683 2.455E-06 0.906 2.058 2.964 3.318E-06 0.137 0.196 0.333 4.412E-06 1.909 2.727 4.636 3.493E-05 1.666 2.282 3.948 14.56 238.5 320122012 4 42012 1.006E-05 0.710 1.614 2.324 7.507E-06 0.836 1.900 2.736 0.000E+00 0.000 0.000 0.000 1.772E-05 1.762 2.516 4.278 4.683E-06 1.795 2.459 4.253 13.59 235.5 420122012 5 52012 2.063E-05 0.750 1.705 2.455 4.887E-06 0.895 2.034 2.930 3.274E-05 1.289 1.842 3.131 1.510E-05 1.709 2.442 4.151 2.987E-06 1.826 2.501 4.328 16.99 233.4 520122012 6 62012 8.530E-06 0.762 1.731 2.493 1.102E-05 0.542 1.231 1.773 1.221E-05 0.174 0.248 0.422 2.380E-05 1.490 2.129 3.619 5.057E-05 1.472 2.016 3.488 11.80 229.0 620122012 7 72012 1.198E-05 0.812 1.845 2.657 2.040E-05 0.835 1.898 2.733 5.313E-08 2.111 3.016 5.127 1.477E-05 1.979 2.827 4.806 6.704E-08 2.174 2.978 5.153 20.48 228.2 720122012 8 82012 1.706E-05 0.434 0.986 1.421 1.268E-05 0.745 1.694 2.439 3.795E-08 1.946 2.781 4.727 4.911E-06 1.278 1.826 3.104 2.579E-06 0.332 0.455 0.788 12.48 222.6 820122012 9 92012 1.582E-05 0.722 1.641 2.363 1.371E-05 0.480 1.090 1.570 1.224E-05 1.460 2.085 3.545 2.212E-05 1.260 1.800 3.060 2.505E-05 0.929 1.273 2.203 12.74 218.6 920122012 10 102012 2.651E-05 0.914 2.078 2.993 0.000E+00 0.000 0.000 0.000 2.441E-07 1.827 2.610 4.438 4.236E-05 2.085 2.979 5.064 3.472E-06 2.120 2.905 5.025 17.52 215.7 1020122012 11 112012 8.947E-06 0.431 0.979 1.409 1.082E-05 0.445 1.011 1.456 1.395E-05 1.955 2.792 4.747 1.265E-09 2.059 2.941 5.000 0.000E+00 2.049 2.807 4.856 17.47 213.3 1120122012 12 122012 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.00 202.0 122012

Month/ Year

Appendix 3e – Past Actual PM10 Emissions



Total PM10 (tons/month)

Total PM10 (24-month Rolling tpy)


of 1

PM25 Fuel Oil

(tons/month)

PM2.5 Filterable -

Coal (tons/month)

PM2.5 Condensable -

Coal (tons/month)


PM25 Fuel Oil

(tons/month)

PM2.5 Filterable -

Coal (tons/month)

PM2.5 Condensable -

Coal (tons/month)


PM25 Fuel Oil

(tons/month)

PM2.5 Filterable -

Coal (tons/month)

PM2.5 Condensable -

Coal (tons/month)


PM25 Fuel Oil

(tons/month)

PM25 Filterable -

Coal (tons/month)

PM25 Condensable -

Coal (tons/month)


PM25 Fuel Oil

(tons/month)

PM25 Filterable -

Coal (tons/month)

PM25 Condensable -

Coal (tons/month)


Emission Factor 1.55 0.0044 0.01 1.55 0.0044 0.01 1.55 0.007 0.01 1.55 0.007 0.01 1.55 0.0073 0.01Emission Factor Units lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtu lb/kgal lb/MMBtu lb/MMBtuControl Efficiency 99.89% 99.89% 99.89% 99.89% 99.89%

2008 4 42008 1.364E-05 1.0279 3.6831 4.7110 4.615E-06 1.314 4.726 6.040 0.000E+00 0.000 0.000 0.000 0.000E+00 2.406 3.437 5.843 0.000E+00 2.420 3.315 5.735 22.33 11.16 420082008 5 52008 8.173E-06 0.7767 2.6602 3.4369 7.480E-06 1.270 4.357 5.628 2.594E-05 1.471 2.101 3.572 1.793E-05 1.951 2.786 4.737 2.949E-06 1.326 1.817 3.143 20.52 21.42 520082008 6 62008 4.120E-06 1.1842 4.0164 5.2006 3.915E-06 1.203 4.081 5.284 0.000E+00 2.346 3.351 5.698 1.690E-05 2.015 2.878 4.893 3.907E-05 1.624 2.224 3.848 24.92 33.88 620082008 7 72008 1.023E-05 1.0725 3.7193 4.7918 8.702E-06 1.099 3.809 4.908 0.000E+00 2.360 3.372 5.733 6.534E-06 2.214 3.162 5.376 6.170E-06 2.509 3.438 5.947 26.76 47.26 720082008 8 82008 2.046E-06 1.3327 4.8394 6.1721 2.838E-06 1.327 4.819 6.146 2.489E-07 2.348 3.355 5.703 1.728E-05 2.014 2.877 4.891 2.285E-05 2.138 2.929 5.068 27.98 61.25 820082008 9 92008 1.152E-05 0.9456 3.5048 4.4504 5.202E-06 1.169 4.341 5.511 0.000E+00 2.234 3.192 5.426 8.201E-07 2.279 3.255 5.534 5.115E-09 2.413 3.305 5.718 26.64 74.57 920082008 10 102008 1.401E-05 0.4105 1.5748 1.9853 8.717E-06 0.860 3.245 4.106 1.910E-06 2.415 3.450 5.864 1.246E-05 2.052 2.931 4.983 0.000E+00 2.546 3.488 6.034 22.97 86.1 1020082008 11 112008 2.488E-06 1.2281 4.7723 6.0004 2.119E-05 0.682 2.656 3.338 5.522E-05 2.035 2.908 4.943 3.501E-05 1.640 2.343 3.983 1.557E-06 1.686 2.310 3.996 22.26 97.2 1120082008 12 122008 7.679E-06 1.2751 5.1192 6.3943 3.254E-06 1.290 5.179 6.469 3.446E-05 1.724 2.463 4.188 2.295E-05 2.057 2.939 4.996 0.000E+00 0.000 0.000 0.000 22.05 108.2 1220082009 1 12009 2.712E-06 1.3039 5.6304 6.9343 6.574E-06 1.372 5.925 7.297 2.055E-07 2.329 3.327 5.656 1.294E-05 2.182 3.117 5.300 1.652E-05 2.070 2.835 4.905 30.09 123.3 120092009 2 22009 3.277E-06 1.0124 4.3716 5.3840 2.912E-06 1.049 4.532 5.581 0.000E+00 2.062 2.946 5.009 7.487E-06 1.792 2.560 4.352 8.525E-09 2.176 2.980 5.156 25.48 136.0 220092009 3 32009 1.229E-05 0.7977 3.4447 4.2425 3.031E-06 0.993 4.289 5.282 3.063E-06 2.047 2.924 4.971 0.000E+00 0.000 0.000 0.000 0.000E+00 2.382 3.264 5.646 20.14 146.1 320092009 4 42009 2.504E-06 1.0160 4.1563 5.1723 2.078E-06 1.005 4.112 5.117 1.862E-05 0.307 0.439 0.746 1.455E-05 1.677 2.396 4.072 2.353E-07 2.277 3.119 5.396 20.50 156.3 420092009 5 52009 8.541E-06 1.1203 4.5832 5.7035 3.168E-06 1.099 4.496 5.595 2.860E-05 1.498 2.139 3.637 3.338E-05 1.735 2.479 4.214 2.046E-05 1.758 2.408 4.165 23.32 168.0 520092009 6 62009 3.094E-06 1.1954 4.8901 6.0855 1.188E-05 0.989 4.047 5.037 0.000E+00 2.193 3.133 5.326 0.000E+00 2.056 2.938 4.994 0.000E+00 2.147 2.941 5.088 26.53 181.2 620092009 7 72009 4.153E-06 1.1957 4.8915 6.0872 3.510E-06 1.263 5.168 6.431 1.161E-06 2.169 3.099 5.268 0.000E+00 2.202 3.146 5.347 0.000E+00 2.323 3.182 5.504 28.64 195.6 720092009 8 82009 1.046E-05 1.0132 4.1448 5.1580 2.610E-06 1.317 5.389 6.706 2.760E-05 1.732 2.475 4.207 9.007E-06 2.121 3.030 5.152 1.428E-05 2.162 2.962 5.124 26.35 208.7 820092009 9 92009 2.418E-06 0.1387 0.5674 0.7061 2.363E-06 1.277 5.224 6.501 6.823E-06 1.883 2.689 4.572 3.693E-06 2.123 3.032 5.155 1.057E-05 1.848 2.532 4.380 21.31 219.4 920092009 10 102009 2.780E-05 0.2013 0.8690 1.0703 6.311E-06 1.035 4.471 5.506 9.804E-08 2.429 3.470 5.899 0.000E+00 2.353 3.362 5.715 1.435E-05 1.885 2.582 4.467 22.66 230.7 1020092009 11 112009 9.416E-06 0.5884 2.5407 3.1291 1.516E-06 0.187 0.808 0.995 7.877E-07 2.164 3.092 5.256 0.000E+00 2.111 3.016 5.127 1.980E-05 1.634 2.238 3.872 18.38 239.9 1120092009 12 122009 5.575E-06 1.2036 5.1974 6.4010 8.847E-06 0.476 2.057 2.533 1.936E-05 1.581 2.259 3.841 1.832E-05 1.619 2.313 3.932 9.377E-09 2.318 3.176 5.494 22.20 251.0 1220092010 1 12010 2.254E-06 1.2191 5.2643 6.4834 2.184E-06 1.268 5.477 6.745 7.734E-06 1.935 2.765 4.700 5.759E-06 2.071 2.958 5.029 1.219E-05 1.291 1.769 3.060 26.02 264.0 120102010 2 22010 5.658E-06 0.9484 4.0953 5.0437 1.147E-06 1.116 4.820 5.936 9.258E-07 2.195 3.136 5.332 1.413E-06 0.876 1.251 2.127 6.387E-06 1.923 2.634 4.556 22.99 275.5 220102010 3 32010 8.095E-06 1.0098 4.3606 5.3705 2.685E-06 1.031 4.452 5.483 2.499E-06 0.942 1.346 2.288 1.856E-05 1.645 2.350 3.995 1.543E-05 2.248 3.079 5.327 22.46 286.7 320102010 4 42010 6.770E-06 0.8395 3.4345 4.2741 1.175E-05 0.738 3.188 3.926 2.589E-05 0.358 0.511 0.869 7.141E-06 2.137 3.053 5.190 7.805E-06 2.276 3.118 5.394 19.65 285.4 420102010 5 52010 2.252E-06 0.5587 2.1584 2.7171 6.923E-06 0.929 3.589 4.518 1.569E-05 1.706 2.437 4.143 0.000E+00 2.289 3.271 5.560 1.724E-05 1.828 2.504 4.331 21.27 285.8 520102010 6 62010 2.546E-06 0.7117 2.7498 3.4615 1.662E-07 0.307 1.188 1.495 2.962E-06 2.026 2.895 4.921 9.718E-08 2.209 3.156 5.365 0.000E+00 2.237 3.065 5.302 20.54 283.6 620102010 7 72010 8.698E-06 0.7815 3.0196 3.8011 2.381E-05 0.492 1.901 2.393 2.109E-05 1.892 2.702 4.594 3.028E-06 2.293 3.276 5.569 5.553E-06 2.369 3.245 5.613 21.97 281.2 720102010 8 82010 1.977E-05 0.7033 2.7175 3.4208 3.011E-06 1.062 4.103 5.165 2.222E-06 2.236 3.194 5.430 1.182E-05 2.087 2.981 5.068 2.123E-05 1.994 2.732 4.726 23.81 279.1 820102010 9 92010 2.499E-06 0.0872 0.3370 0.4242 5.227E-06 0.938 3.624 4.562 7.775E-06 2.055 2.936 4.992 8.597E-06 2.081 2.973 5.054 3.175E-06 2.382 3.263 5.644 20.68 276.1 920102010 10 102010 1.159E-05 1.0809 4.1763 5.2572 8.053E-06 0.314 1.215 1.529 9.546E-06 2.038 2.912 4.950 5.043E-06 2.363 3.375 5.738 6.574E-06 2.478 3.394 5.872 23.35 276.3 1020102010 11 112010 2.040E-06 1.2304 4.7540 5.9844 1.383E-05 0.883 3.411 4.293 9.360E-07 2.248 3.211 5.459 7.243E-06 2.066 2.952 5.018 1.556E-06 0.653 0.894 1.547 22.30 276.3 1120102010 12 122010 2.734E-06 1.2461 4.8145 6.0606 3.551E-06 1.226 4.738 5.964 1.931E-05 2.084 2.978 5.062 1.689E-05 2.251 3.215 5.466 0.000E+00 0.000 0.000 0.000 22.55 276.6 1220102011 1 12011 1.648E-06 0.9912 2.2526 3.2438 3.267E-06 0.773 1.756 2.529 1.378E-05 1.823 2.605 4.428 1.559E-05 1.546 2.208 3.754 2.637E-05 1.875 2.569 4.445 18.40 270.8 120112011 2 22011 9.507E-06 0.2946 0.6695 0.9641 8.693E-06 0.689 1.566 2.255 3.218E-06 2.099 2.999 5.098 4.176E-06 1.923 2.748 4.671 8.525E-09 2.141 2.933 5.074 18.06 267.0 220112011 3 32011 6.752E-06 0.9879 3.8171 4.8050 1.406E-06 0.997 3.851 4.848 1.034E-05 2.027 2.896 4.923 1.146E-06 0.268 0.383 0.651 1.254E-05 2.161 2.961 5.122 20.35 267.1 320112011 4 42011 6.626E-06 0.8712 3.3659 4.2371 6.403E-06 0.621 2.399 3.020 1.071E-05 1.923 2.747 4.671 3.157E-05 1.144 1.635 2.779 2.063E-07 2.353 3.223 5.576 20.28 267.0 420112011 5 52011 6.007E-06 0.6268 2.4218 3.0486 4.926E-06 1.059 4.092 5.151 7.476E-06 0.970 1.385 2.355 2.902E-05 1.918 2.740 4.658 2.523E-05 2.003 2.744 4.747 19.96 265.4 520112011 6 62011 1.060E-05 0.8928 3.4496 4.3425 1.971E-06 0.622 2.404 3.026 1.511E-05 2.098 2.996 5.094 1.362E-05 1.969 2.813 4.782 1.736E-05 2.019 2.765 4.784 22.03 263.1 620112011 7 72011 8.248E-06 0.9325 3.3478 4.2804 6.978E-06 0.682 2.790 3.472 9.771E-06 1.975 3.386 5.361 0.000E+00 2.115 3.021 5.136 8.867E-06 2.132 3.504 5.636 23.88 260.7 720112011 8 82011 1.192E-05 0.4937 1.4586 1.9523 8.360E-06 1.036 4.237 5.273 1.231E-05 1.891 2.701 4.592 1.334E-05 2.025 2.893 4.918 1.166E-05 2.020 2.767 4.787 21.52 258.3 820112011 9 92011 0.000E+00 0.0000 0.0000 0.0000 7.758E-08 0.989 3.371 4.360 5.805E-06 1.982 2.831 4.813 1.449E-05 1.984 2.835 4.819 2.979E-05 1.717 2.352 4.069 18.06 256.7 920112011 10 102011 0.000E+00 0.0000 0.0000 0.0000 8.152E-06 0.901 3.070 3.971 1.428E-05 1.707 2.439 4.146 9.471E-07 2.213 3.162 5.375 1.176E-05 2.111 2.892 5.004 18.50 254.6 1020112011 11 112011 2.221E-05 0.4283 0.9734 1.4017 7.037E-06 0.580 1.318 1.898 9.000E-06 1.880 2.686 4.567 5.504E-06 2.111 3.016 5.127 2.276E-07 2.229 3.054 5.283 18.28 254.6 1120112011 12 122011 4.542E-06 0.9190 2.0887 3.0077 1.189E-05 0.768 1.746 2.514 1.452E-05 2.009 2.870 4.880 3.031E-05 1.715 2.450 4.166 2.649E-06 0.696 0.953 1.648 16.22 251.6 1220112012 1 12012 8.530E-06 0.7911 1.7980 2.5892 9.601E-06 0.825 1.875 2.699 1.870E-05 0.597 0.853 1.451 2.488E-06 2.075 2.964 5.039 1.858E-05 1.822 2.496 4.317 16.10 246.6 120122012 2 22012 1.452E-05 0.7830 1.7796 2.5627 7.121E-06 0.821 1.865 2.686 3.074E-06 1.879 2.684 4.564 9.023E-06 0.090 0.129 0.219 3.147E-06 1.987 2.721 4.708 14.74 242.5 220122012 3 32012 6.629E-06 0.8199 1.8635 2.6834 1.655E-06 0.906 2.058 2.964 2.236E-06 0.137 0.196 0.333 2.974E-06 1.909 2.727 4.636 2.354E-05 1.666 2.282 3.948 14.56 238.5 320122012 4 42012 6.782E-06 0.7101 1.6140 2.3241 5.059E-06 0.836 1.900 2.736 0.000E+00 0.000 0.000 0.000 1.194E-05 1.762 2.516 4.278 3.156E-06 1.795 2.459 4.253 13.59 235.5 420122012 5 52012 1.390E-05 0.7503 1.7052 2.4555 3.293E-06 0.895 2.034 2.930 2.207E-05 1.289 1.842 3.131 1.018E-05 1.709 2.442 4.151 2.013E-06 1.826 2.501 4.328 16.99 233.4 520122012 6 62012 5.748E-06 0.7618 1.7313 2.4930 7.425E-06 0.542 1.231 1.773 8.228E-06 0.174 0.248 0.422 1.604E-05 1.490 2.129 3.619 3.408E-05 1.472 2.016 3.488 11.80 229.0 620122012 7 72012 8.071E-06 0.8119 1.8453 2.6572 1.375E-05 0.835 1.898 2.733 3.580E-08 2.111 3.016 5.127 9.954E-06 1.979 2.827 4.806 4.518E-08 2.174 2.978 5.153 20.48 228.2 720122012 8 82012 1.150E-05 0.4341 0.9865 1.4206 8.546E-06 0.745 1.694 2.439 2.557E-08 1.946 2.781 4.727 3.309E-06 1.278 1.826 3.104 1.738E-06 0.332 0.455 0.788 12.48 222.6 820122012 9 92012 1.066E-05 0.7219 1.6407 2.3625 9.239E-06 0.480 1.090 1.570 8.247E-06 1.460 2.085 3.545 1.490E-05 1.260 1.800 3.060 1.688E-05 0.929 1.273 2.203 12.74 218.6 920122012 10 102012 1.786E-05 0.9144 2.0783 2.9927 0.000E+00 0.000 0.000 0.000 1.645E-07 1.827 2.610 4.438 2.855E-05 2.085 2.979 5.064 2.340E-06 2.120 2.905 5.025 17.52 215.7 1020122012 11 112012 6.030E-06 0.4306 0.9787 1.4093 7.292E-06 0.445 1.011 1.456 9.401E-06 1.955 2.792 4.747 8.525E-10 2.059 2.941 5.000 0.000E+00 2.049 2.807 4.856 17.47 213.3 1120122012 12 122012 0.000E+00 0.0000 0.0000 0.0000 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.000E+00 0.000 0.000 0.000 0.00 202.0 122012

Month/Year

Appendix 3f – Past Actual PM2.5 Emissions



Total PM25 (tons/month)

Total PM25 24-month

Rolling (tpy)


of 1

Year Month

Unit 5SO2

(tons/month)

Unit 6SO2

(tons/month)

Unit 7SO2

(tons/month)

Unit 8SO2

(tons/month)

Unit 9SO2

(tons/month)Total SO2

(tons/month)

Total SO2 24-month rolling

(tpy)2008 4 174.4 245.7 0.0 166.0 168.8 755.0 3772008 5 127.0 224.9 109.5 136.0 82.6 679.9 7172008 6 200.3 212.5 149.7 153.9 133.9 850.3 1,1432008 7 189.9 201.8 170.5 175.9 182.0 920.1 1,6032008 8 233.0 239.2 151.5 155.6 152.3 931.7 2,0682008 9 169.4 215.7 150.8 161.8 164.4 862.1 2,4992008 10 77.6 185.5 160.5 154.5 174.5 752.4 2,8762008 11 220.8 133.1 144.7 132.6 110.3 741.6 3,2462008 12 228.6 233.3 125.0 163.3 0.0 750.1 3,6222009 1 244.7 248.0 162.0 168.0 149.1 971.8 4,1072009 2 191.6 191.1 145.0 142.5 153.2 823.4 4,5192009 3 161.4 202.0 158.2 0.0 173.3 695.0 4,8672009 4 189.6 186.4 28.9 139.2 155.2 699.3 5,2162009 5 203.9 200.5 106.7 144.2 125.0 780.2 5,6062009 6 210.4 179.3 148.8 160.3 157.9 856.7 6,0352009 7 214.0 231.2 143.8 168.0 167.8 924.8 6,4972009 8 177.7 236.8 116.2 150.0 143.0 823.7 6,9092009 9 24.6 234.6 128.5 159.3 134.0 680.9 7,2492009 10 35.5 185.5 159.2 174.4 148.4 703.0 7,6012009 11 103.8 32.6 143.6 155.4 118.9 554.4 7,8782009 12 208.9 85.9 107.6 120.5 147.1 669.9 8,2132010 1 206.8 225.5 130.9 145.6 85.9 794.6 8,6102010 2 170.0 204.2 141.6 66.5 138.1 720.4 8,9712010 3 180.3 187.1 60.8 124.9 150.3 703.4 9,3222010 4 144.2 129.4 43.2 151.4 149.3 617.5 9,2542010 5 93.1 155.7 114.4 156.3 129.1 648.6 9,2382010 6 123.6 52.6 140.9 153.3 153.1 623.5 9,1252010 7 146.5 90.6 136.7 163.0 161.3 698.2 9,0142010 8 130.4 193.2 138.8 146.6 130.8 739.8 8,9182010 9 15.1 157.2 142.4 152.0 162.0 628.7 8,8012010 10 188.7 54.6 145.0 171.4 169.0 728.6 8,7892010 11 274.7 214.5 149.5 148.9 45.2 832.7 8,8352010 12 313.8 319.4 145.0 161.3 0.0 939.6 8,9292011 1 182.2 190.8 117.3 119.5 125.5 735.3 8,8112011 2 40.9 109.1 138.7 144.1 142.7 575.5 8,6872011 3 203.4 210.7 138.7 19.3 153.3 725.4 8,7022011 4 168.4 133.0 132.4 92.2 139.6 665.6 8,6862011 5 137.7 224.6 71.6 151.5 145.4 730.8 8,6612011 6 136.4 125.5 131.0 141.8 125.8 660.6 8,5632011 7 228.2 167.9 137.0 156.8 143.2 833.1 8,5172011 8 104.1 225.9 125.9 142.1 140.0 738.1 8,4742011 9 0.0 174.8 136.8 146.5 129.0 587.0 8,4272011 10 0.0 169.4 128.3 161.4 151.0 610.1 8,3812011 11 50.3 97.1 137.6 155.7 152.2 592.9 8,4002011 12 111.6 95.2 138.3 135.6 43.5 524.3 8,3272012 1 98.7 105.6 54.3 151.9 134.2 544.6 8,2022012 2 94.3 99.8 133.7 19.6 143.1 490.6 8,0872012 3 95.2 108.5 10.6 134.1 126.7 475.1 7,9732012 4 80.1 97.4 0.0 124.2 120.7 422.4 7,8762012 5 95.2 119.2 108.8 126.1 137.4 586.7 7,8452012 6 87.7 67.2 16.3 105.2 106.0 382.4 7,7242012 7 94.5 105.1 147.6 149.0 156.8 653.0 7,7012012 8 51.3 94.9 140.0 99.2 29.5 414.9 7,5392012 9 88.4 61.2 110.8 96.4 75.8 432.6 7,4412012 10 108.4 0.0 137.2 154.3 152.9 552.7 7,3532012 11 51.8 60.8 145.6 151.9 152.4 562.5 7,2182012 12 0.0 97.4 141.3 123.6 148.5 510.8 7,004

Appendix 3g – Past Actual SO2 Emissions



of 1

VOC Fuel Oil (tons/month)

VOC Coal (tons/month)

VOC Total (tons/month)













0.2 0.06 2 0.06 2 0.06 2 0.06 2 0.06lb/kgal lbs/ton lb/kgal lbs/ton lb/kgal lbs/ton lb/kgal lbs/ton lb/kgal lbs/ton

2008 4 42008 1.600E-03 0.5888 0.5904 5.414E-03 0.7525 0.7579 0.000E+00 0.0000 0.0000 0.000E+00 1.1385 1.1385 0.000E+00 1.0980 1.0980 3.585 1.792 420082008 5 52008 9.587E-04 0.4481 0.4491 8.774E-03 0.7320 0.7407 3.043E-02 0.6960 0.7265 2.103E-02 0.9230 0.9440 3.459E-03 0.6018 0.6053 3.466 3.525 520082008 6 62008 4.833E-04 0.6872 0.6877 4.592E-03 0.6982 0.7028 0.000E+00 1.1103 1.1103 1.982E-02 0.9535 0.9733 4.583E-02 0.7368 0.7826 4.257 5.654 620082008 7 72008 1.200E-03 0.6226 0.6238 1.021E-02 0.6377 0.6479 0.000E+00 1.1172 1.1172 7.664E-03 1.0478 1.0554 7.237E-03 1.1389 1.1462 4.591 7.949 720082008 8 82008 2.400E-04 0.7765 0.7767 3.329E-03 0.7733 0.7766 2.920E-04 1.1116 1.1119 2.027E-02 0.9533 0.9736 2.680E-02 0.9706 0.9974 4.636 10.267 820082008 9 92008 1.351E-03 0.5473 0.5487 6.102E-03 0.6759 0.6820 0.000E+00 1.0579 1.0579 9.620E-04 1.0789 1.0799 6.000E-06 1.0955 1.0955 4.464 12.499 920082008 10 102008 1.643E-03 0.2336 0.2352 1.023E-02 0.4918 0.5020 2.241E-03 1.1436 1.1458 1.462E-02 0.9718 0.9864 0.000E+00 1.1563 1.1563 4.026 14.512 1020082008 11 112008 2.918E-04 0.6995 0.6998 2.485E-02 0.3883 0.4132 6.477E-02 0.9651 1.0299 4.107E-02 0.7777 0.8187 1.826E-03 0.7666 0.7684 3.730 16.377 1120082008 12 122008 9.008E-04 0.7324 0.7333 3.817E-03 0.7409 0.7447 4.043E-02 0.8180 0.8584 2.693E-02 0.9757 1.0026 0.000E+00 0.0000 0.0000 3.339 18.046 1220082009 1 12009 3.181E-04 0.7526 0.7530 7.712E-03 0.7920 0.7997 2.410E-04 1.1049 1.1051 1.518E-02 1.0353 1.0505 1.938E-02 0.9416 0.9610 4.669 20.381 120092009 2 22009 3.844E-04 0.5844 0.5848 3.416E-03 0.6058 0.6092 0.000E+00 0.9785 0.9785 8.782E-03 0.8502 0.8590 1.000E-05 0.9899 0.9899 4.021 22.392 220092009 3 32009 1.442E-03 0.4605 0.4619 3.556E-03 0.5733 0.5768 3.593E-03 0.9711 0.9747 0.000E+00 0.0000 0.0000 0.000E+00 1.0839 1.0839 3.097 23.940 320092009 4 42009 2.937E-04 0.5886 0.5889 2.437E-03 0.5823 0.5848 2.184E-02 0.1457 0.1675 1.707E-02 0.7958 0.8128 2.760E-04 1.0362 1.0365 3.191 25.535 420092009 5 52009 1.002E-03 0.6523 0.6533 3.716E-03 0.6400 0.6437 3.354E-02 0.7107 0.7442 3.916E-02 0.8235 0.8626 2.400E-02 0.7998 0.8238 3.728 27.399 520092009 6 62009 3.629E-04 0.6965 0.6968 1.394E-02 0.5764 0.5903 0.000E+00 1.0445 1.0445 0.000E+00 0.9794 0.9794 0.000E+00 0.9805 0.9805 4.292 29.545 620092009 7 72009 4.871E-04 0.6991 0.6995 4.117E-03 0.7385 0.7426 1.362E-03 1.0358 1.0371 0.000E+00 1.0512 1.0512 0.000E+00 1.0634 1.0634 4.594 31.842 720092009 8 82009 1.228E-03 0.5930 0.5942 3.061E-03 0.7710 0.7741 3.238E-02 0.8217 0.8540 1.057E-02 1.0062 1.0168 1.675E-02 0.9835 1.0002 4.239 33.962 820092009 9 92009 2.836E-04 0.0812 0.0815 2.772E-03 0.7472 0.7500 8.004E-03 0.8928 0.9008 4.332E-03 1.0067 1.0110 1.239E-02 0.8405 0.8528 3.596 35.760 920092009 10 102009 3.261E-03 0.1173 0.1206 7.403E-03 0.6037 0.6111 1.150E-04 1.1519 1.1521 0.000E+00 1.1160 1.1160 1.683E-02 0.8571 0.8739 3.874 37.697 1020092009 11 112009 1.105E-03 0.3429 0.3440 1.778E-03 0.1091 0.1108 9.240E-04 1.0265 1.0274 0.000E+00 1.0012 1.0012 2.323E-02 0.7430 0.7662 3.250 39.321 1120092009 12 122009 6.540E-04 0.7016 0.7022 1.038E-02 0.2777 0.2881 2.271E-02 0.7498 0.7725 2.149E-02 0.7677 0.7892 1.100E-05 1.0541 1.0542 3.606 41.124 1220092010 1 12010 2.644E-04 0.7106 0.7109 2.562E-03 0.7393 0.7419 9.072E-03 0.9176 0.9267 6.755E-03 0.9818 0.9885 1.430E-02 0.5871 0.6014 3.969 43.109 120102010 2 22010 6.637E-04 0.5528 0.5535 1.346E-03 0.6506 0.6519 1.086E-03 1.0409 1.0420 1.658E-03 0.4154 0.4170 7.492E-03 0.8741 0.8816 3.546 44.882 220102010 3 32010 9.496E-04 0.5886 0.5896 3.150E-03 0.6010 0.6041 2.931E-03 0.4467 0.4497 2.178E-02 0.7800 0.8018 1.810E-02 1.0219 1.0400 3.485 46.625 320102010 4 42010 7.941E-04 0.4886 0.4894 1.379E-02 0.4299 0.4437 3.037E-02 0.1697 0.2000 8.377E-03 1.0134 1.0218 9.155E-03 1.0350 1.0442 3.199 46.432 420102010 5 52010 2.642E-04 0.3241 0.3243 8.121E-03 0.5389 0.5470 1.841E-02 0.8102 0.8286 0.000E+00 1.0874 1.0874 2.022E-02 0.8324 0.8526 3.640 46.519 520102010 6 62010 2.987E-04 0.4128 0.4131 1.950E-04 0.1782 0.1784 3.475E-03 0.9627 0.9662 1.140E-04 1.0496 1.0497 0.000E+00 1.0193 1.0193 3.627 46.204 620102010 7 72010 1.020E-03 0.4542 0.4552 2.793E-02 0.2862 0.3142 2.474E-02 0.8989 0.9236 3.552E-03 1.0896 1.0932 6.514E-03 1.0793 1.0858 3.872 45.845 720102010 8 82010 2.320E-03 0.4096 0.4119 3.532E-03 0.6184 0.6220 2.606E-03 1.0613 1.0639 1.386E-02 0.9904 1.0043 2.491E-02 0.9077 0.9326 4.035 45.544 820102010 9 92010 2.931E-04 0.0508 0.0511 6.131E-03 0.5462 0.5523 9.120E-03 0.9758 0.9850 1.008E-02 0.9881 0.9982 3.724E-03 1.0844 1.0881 3.675 45.149 920102010 10 102010 1.359E-03 0.6347 0.6360 9.446E-03 0.1833 0.1927 1.120E-02 0.9680 0.9792 5.915E-03 1.1223 1.1282 7.712E-03 1.1286 1.1363 4.072 45.173 1020102010 11 112010 2.393E-04 0.7230 0.7232 1.622E-02 0.5187 0.5349 1.098E-03 1.0675 1.0686 8.496E-03 0.9814 0.9899 1.825E-03 0.2973 0.2991 3.616 45.115 1120102010 12 122010 3.207E-04 0.7322 0.7325 4.165E-03 0.7205 0.7246 2.265E-02 0.9895 1.0121 1.981E-02 1.0684 1.0882 0.000E+00 0.0000 0.0000 3.557 45.225 1220102011 1 12011 1.933E-04 0.7318 0.7320 3.832E-03 0.5282 0.5320 1.617E-02 0.8653 0.8815 1.829E-02 0.7337 0.7520 3.093E-02 0.8534 0.8844 3.782 44.781 120112011 2 22011 1.115E-03 0.2211 0.2222 1.020E-02 0.5071 0.5173 3.775E-03 0.9962 1.0000 4.899E-03 0.9128 0.9176 1.000E-05 0.9743 0.9744 3.631 44.586 220112011 3 32011 7.920E-04 0.5804 0.5812 1.649E-03 0.5857 0.5873 1.212E-02 0.9618 0.9740 1.344E-03 0.1271 0.1285 1.471E-02 0.9834 0.9981 3.269 44.672 320112011 4 42011 7.772E-04 0.5110 0.5117 7.511E-03 0.3643 0.3718 1.256E-02 0.9123 0.9248 3.703E-02 0.5427 0.5798 2.420E-04 1.0702 1.0704 3.459 44.806 420112011 5 52011 7.046E-04 0.3661 0.3668 5.778E-03 0.6180 0.6238 8.770E-03 0.4601 0.4688 3.404E-02 0.9097 0.9438 2.960E-02 0.9112 0.9408 3.344 44.614 520112011 6 62011 1.243E-03 0.5205 0.5218 2.312E-03 0.3628 0.3651 1.772E-02 0.9963 1.0140 1.598E-02 0.9353 0.9512 2.037E-02 0.9194 0.9397 3.792 44.364 620112011 7 72011 9.675E-04 0.5568 0.5577 8.185E-03 0.3951 0.4033 1.146E-02 0.9381 0.9496 0.000E+00 1.0045 1.0045 1.040E-02 0.9709 0.9813 3.896 44.015 720112011 8 82011 1.398E-03 0.2944 0.2958 9.807E-03 0.5890 0.5988 1.444E-02 0.8981 0.9125 1.565E-02 0.9619 0.9775 1.368E-02 0.9202 0.9338 3.718 43.755 820112011 9 92011 0.000E+00 0.0000 0.0000 9.100E-05 0.5678 0.5679 6.809E-03 0.9410 0.9478 1.700E-02 0.9422 0.9592 3.495E-02 0.7817 0.8167 3.292 43.603 920112011 10 102011 0.000E+00 0.0000 0.0000 9.563E-03 0.5158 0.5253 1.675E-02 0.8104 0.8271 1.111E-03 1.0506 1.0517 1.380E-02 0.9611 0.9749 3.379 43.355 1020112011 11 112011 2.606E-03 0.3237 0.3263 8.254E-03 0.4123 0.4205 1.056E-02 0.8932 0.9038 6.456E-03 1.0028 1.0092 2.670E-04 1.0155 1.0157 3.676 43.568 1120112011 12 122011 5.328E-04 0.6949 0.6955 1.395E-02 0.5810 0.5949 1.703E-02 0.9550 0.9720 3.556E-02 0.8152 0.8508 3.107E-03 0.3170 0.3201 3.433 43.482 1220112012 1 12012 1.001E-03 0.5981 0.5991 1.126E-02 0.6236 0.6348 2.193E-02 0.2839 0.3058 2.919E-03 0.9859 0.9888 2.180E-02 0.8301 0.8519 3.380 43.187 120122012 2 22012 1.704E-03 0.5919 0.5936 8.353E-03 0.6204 0.6287 3.606E-03 0.8928 0.8964 1.058E-02 0.0428 0.0534 3.692E-03 0.9051 0.9088 3.081 42.955 220122012 3 32012 7.776E-04 0.6200 0.6208 1.941E-03 0.6848 0.6868 2.623E-03 0.0651 0.0677 3.488E-03 0.9074 0.9108 2.762E-02 0.7593 0.7869 3.073 42.749 320122012 4 42012 7.956E-04 0.5377 0.5385 5.934E-03 0.6329 0.6388 0.000E+00 0.0000 0.0000 1.401E-02 0.8384 0.8524 3.702E-03 0.8191 0.8228 2.852 42.575 420122012 5 52012 1.631E-03 0.5681 0.5697 3.863E-03 0.6778 0.6816 2.588E-02 0.6135 0.6394 1.194E-02 0.8135 0.8254 2.361E-03 0.8334 0.8357 3.552 42.531 520122012 6 62012 6.743E-04 0.5765 0.5771 8.710E-03 0.4100 0.4187 9.652E-03 0.0827 0.0923 1.881E-02 0.7087 0.7275 3.997E-02 0.6713 0.7113 2.527 41.982 620122012 7 72012 9.468E-04 0.6143 0.6152 1.613E-02 0.6319 0.6480 4.200E-05 1.0040 1.0040 1.168E-02 0.9411 0.9528 5.300E-05 0.9915 0.9915 4.212 42.151 720122012 8 82012 1.349E-03 0.3281 0.3295 1.003E-02 0.5635 0.5735 3.000E-05 0.9249 0.9249 3.882E-03 0.6075 0.6114 2.039E-03 0.1515 0.1536 2.593 41.430 820122012 9 92012 1.250E-03 0.5456 0.5468 1.084E-02 0.3625 0.3734 9.674E-03 0.6934 0.7031 1.748E-02 0.5986 0.6161 1.981E-02 0.4233 0.4431 2.682 40.934 920122012 10 102012 2.095E-03 0.6908 0.6929 0.000E+00 0.0000 0.0000 1.930E-04 0.8678 0.8680 3.349E-02 0.9903 1.0238 2.745E-03 0.9655 0.9682 3.553 40.675 1020122012 11 112012 7.073E-04 0.3253 0.3260 8.554E-03 0.3359 0.3445 1.103E-02 0.9278 0.9389 1.000E-06 0.9773 0.9773 0.000E+00 0.9328 0.9328 3.519 40.626 112012

Total VOC (tons/month)

Month/ Year

Total VOC 24-month

Rolling (tpy)Emission Factor

Emission Factor UnitsControl Efficiency

Unit 8 Unit 9

Appendix 3h – Past Actual VOC Emissions


Unit 5 Unit 6 Unit 7


of 1

Year Month Month/Year

Unit 5CO2

(tons/month)

Unit 6CO2

(tons/month)

Unit 7CO2

(tons/month)

Unit 8CO2

(tons/month)

Unit 9CO2

(tons/month)

Total CO2 (tons/month

)

Total CO2 24-month

rolling (tpy)

2008 4 42008 44,485 60,392 0 71,358 73,068 249,303 124,6522008 5 52008 33,355 58,594 47,502 59,397 35,737 234,584 241,9432008 6 62008 53,026 56,128 61,774 63,159 53,936 288,023 385,9552008 7 72008 48,101 51,021 68,679 71,528 73,960 313,288 542,5992008 8 82008 59,591 61,035 65,688 66,995 65,998 319,307 702,2522008 9 92008 42,556 54,355 66,220 71,596 70,610 305,338 854,9212008 10 102008 19,179 42,021 68,564 66,659 74,586 271,008 990,4252008 11 112008 53,988 32,288 61,563 56,529 46,301 250,669 1,115,7602008 12 122008 56,619 59,009 51,416 66,968 0 234,012 1,232,7662009 1 12009 57,836 58,543 67,164 70,866 62,784 317,192 1,391,3622009 2 22009 44,842 44,605 59,553 59,721 63,572 272,292 1,527,5082009 3 32009 35,847 45,272 64,154 0 70,032 215,305 1,635,1602009 4 42009 45,432 45,443 11,599 55,894 62,452 220,819 1,745,5702009 5 52009 49,761 50,239 43,256 58,910 51,702 253,868 1,872,5042009 6 62009 54,278 46,058 61,560 66,029 66,415 294,340 2,019,6742009 7 72009 53,237 58,693 59,798 71,532 71,630 314,890 2,177,1192009 8 82009 45,127 60,546 52,105 66,634 63,728 288,140 2,321,1882009 9 92009 6,242 59,259 56,134 69,209 58,912 249,756 2,446,0672009 10 102009 9,285 46,826 67,421 72,850 60,748 257,129 2,574,6312009 11 112009 26,612 8,170 62,089 66,827 52,153 215,851 2,682,5572009 12 122009 53,279 22,110 48,343 53,419 66,397 243,548 2,804,3312010 1 12010 53,462 57,457 57,698 64,566 38,632 271,814 2,940,2382010 2 22010 41,943 50,281 61,880 28,799 59,524 242,426 3,061,4512010 3 32010 44,698 45,878 26,118 54,099 63,984 234,778 3,178,8402010 4 42010 37,693 32,906 17,854 62,826 62,010 213,288 3,160,8322010 5 52010 26,209 42,670 51,375 68,030 57,233 245,517 3,166,2992010 6 62010 33,890 13,945 62,340 66,715 67,029 243,920 3,144,2472010 7 72010 36,932 23,046 58,574 70,470 69,873 258,895 3,117,0512010 8 82010 33,422 48,243 61,950 66,319 59,972 269,906 3,092,3502010 9 92010 4,132 42,935 60,923 64,588 69,228 241,806 3,060,5842010 10 102010 50,359 14,546 60,732 72,186 71,731 269,554 3,059,8572010 11 112010 59,057 44,002 65,109 66,456 19,263 253,885 3,061,4652010 12 122010 59,592 61,423 62,522 71,686 0 255,224 3,072,0712011 1 12011 52,366 41,509 49,879 52,358 54,834 250,946 3,038,9482011 2 22011 15,295 37,300 58,915 63,210 62,759 237,479 3,021,5412011 3 32011 47,551 49,833 59,351 8,442 67,690 232,868 3,030,3232011 4 42011 40,147 30,880 58,013 40,777 62,010 231,826 3,035,8272011 5 52011 29,234 50,870 28,725 59,879 57,315 226,024 3,021,9042011 6 62011 39,464 30,793 60,433 64,313 57,736 252,739 3,001,1042011 7 72011 44,809 33,102 60,388 67,882 62,148 268,327 2,977,8232011 8 82011 24,341 48,888 55,532 62,431 62,035 253,227 2,960,3662011 9 92011 0 47,523 57,115 60,926 54,274 219,837 2,945,4062011 10 102011 0 41,822 53,682 67,141 63,263 225,907 2,929,7952011 11 112011 21,278 30,669 58,437 66,353 64,906 241,644 2,942,6922011 12 122011 44,776 37,398 57,918 56,656 20,613 217,362 2,929,5992012 1 12012 39,052 41,081 21,446 61,427 55,342 218,348 2,902,8662012 2 22012 38,615 40,825 54,687 7,973 58,490 200,590 2,881,9482012 3 32012 39,529 44,544 4,412 55,710 53,437 197,632 2,863,3752012 4 42012 35,161 42,466 0 55,100 54,806 187,533 2,850,4972012 5 52012 36,862 44,242 43,095 49,841 55,125 229,166 2,842,3212012 6 62012 36,024 26,487 6,777 43,807 44,654 157,750 2,799,2362012 7 72012 38,640 41,457 62,043 62,948 66,291 271,379 2,805,4792012 8 82012 20,765 37,044 57,473 40,776 11,895 167,953 2,754,5022012 9 92012 34,272 23,908 42,917 37,919 29,879 168,896 2,718,0472012 10 102012 43,253 0 55,474 64,592 63,690 227,009 2,696,7742012 11 112012 20,451 22,251 59,904 63,892 62,953 229,450 2,684,5572012 12 122012 0 36,087 58,473 51,939 62,166 208,666 2,661,278

Appendix 3i – Past Actual CO2 Emissions



of 1

Methane Fuel Oil

(tons/month)

Methane Coal

(tons/month)

Methane Total

(tons/month)

Methane Fuel Oil

(tons/month)Methane Coal (tons/month)

Methane Total

(tons/month)

Methane Fuel Oil

(tons/month)

Methane Coal

(tons/month)

Methane Total

(tons/month)

Methane Fuel Oil

(tons/month)

Methane Coal

(tons/month)

Methane Total

(tons/month)

Methane Fuel Oil

(tons/month)

Methane Coal

(tons/month)

Methane Total

(tons/month)6.62E-03 0.04 6.62E-03 0.04 6.62E-03 0.04 6.62E-03 0.04 6.62E-03 0.04lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton

138,500.0 138,500.0 138,500.0 138,500.0 138,500.0 2008 4 42008 7.331E-03 0.3925 0.3998 2.480E-03 0.5017 0.5042 0.000E+00 0.0000 0.0000 0.000E+00 0.7590 0.7590 0.000E+00 0.7320 0.7320 2.395 1.198 420082008 5 52008 4.392E-03 0.2987 0.3031 4.019E-03 0.4880 0.4920 1.394E-02 0.4640 0.4780 9.635E-03 0.6153 0.6250 1.585E-03 0.4012 0.4028 2.301 2.348 520082008 6 62008 2.214E-03 0.4582 0.4604 2.104E-03 0.4655 0.4676 0.000E+00 0.7402 0.7402 9.080E-03 0.6357 0.6448 2.099E-02 0.4912 0.5122 2.825 3.760 620082008 7 72008 5.495E-03 0.4151 0.4206 4.676E-03 0.4252 0.4298 0.000E+00 0.7448 0.7448 3.511E-03 0.6985 0.7020 3.315E-03 0.7593 0.7626 3.060 5.290 720082008 8 82008 1.099E-03 0.5177 0.5188 1.525E-03 0.5155 0.5170 1.338E-04 0.7410 0.7412 9.284E-03 0.6356 0.6448 1.228E-02 0.6471 0.6593 3.081 6.831 820082008 9 92008 6.190E-03 0.3649 0.3711 2.795E-03 0.4506 0.4534 0.000E+00 0.7053 0.7053 4.407E-04 0.7193 0.7197 2.749E-06 0.7303 0.7303 2.980 8.321 920082008 10 102008 7.526E-03 0.1557 0.1632 4.684E-03 0.3278 0.3325 1.027E-03 0.7624 0.7634 6.698E-03 0.6479 0.6546 0.000E+00 0.7708 0.7708 2.685 9.663 1020082008 11 112008 1.337E-03 0.4663 0.4677 1.138E-02 0.2589 0.2703 2.967E-02 0.6434 0.6731 1.881E-02 0.5184 0.5373 8.365E-04 0.5110 0.5119 2.460 10.893 1120082008 12 122008 4.126E-03 0.4883 0.4924 1.749E-03 0.4939 0.4957 1.852E-02 0.5453 0.5638 1.233E-02 0.6505 0.6628 0.000E+00 0.0000 0.0000 2.215 12.001 1220082009 1 12009 1.457E-03 0.5018 0.5032 3.533E-03 0.5280 0.5316 1.104E-04 0.7366 0.7367 6.956E-03 0.6902 0.6972 8.880E-03 0.6277 0.6366 3.105 13.553 120092009 2 22009 1.761E-03 0.3896 0.3913 1.565E-03 0.4039 0.4054 0.000E+00 0.6523 0.6523 4.023E-03 0.5668 0.5708 4.581E-06 0.6599 0.6599 2.680 14.893 220092009 3 32009 6.606E-03 0.3070 0.3136 1.629E-03 0.3822 0.3838 1.646E-03 0.6474 0.6491 0.000E+00 0.0000 0.0000 0.000E+00 0.7226 0.7226 2.069 15.928 320092009 4 42009 1.345E-03 0.3924 0.3937 1.116E-03 0.3882 0.3893 1.000E-02 0.0971 0.1071 7.819E-03 0.5305 0.5383 1.264E-04 0.6908 0.6909 2.119 16.987 420092009 5 52009 4.590E-03 0.4348 0.4394 1.702E-03 0.4266 0.4283 1.537E-02 0.4738 0.4892 1.794E-02 0.5490 0.5669 1.100E-02 0.5332 0.5442 2.468 18.221 520092009 6 62009 1.662E-03 0.4643 0.4660 6.384E-03 0.3842 0.3906 0.000E+00 0.6964 0.6964 0.000E+00 0.6529 0.6529 0.000E+00 0.6537 0.6537 2.860 19.651 620092009 7 72009 2.231E-03 0.4660 0.4683 1.886E-03 0.4923 0.4942 6.239E-04 0.6905 0.6911 0.000E+00 0.7008 0.7008 0.000E+00 0.7089 0.7089 3.063 21.183 720092009 8 82009 5.623E-03 0.3953 0.4010 1.402E-03 0.5140 0.5154 1.483E-02 0.5478 0.5626 4.840E-03 0.6708 0.6756 7.673E-03 0.6556 0.6633 2.818 22.592 820092009 9 92009 1.299E-03 0.0541 0.0554 1.270E-03 0.4981 0.4994 3.667E-03 0.5952 0.5988 1.984E-03 0.6711 0.6731 5.677E-03 0.5603 0.5660 2.393 23.788 920092009 10 102009 1.494E-02 0.0782 0.0931 3.391E-03 0.4025 0.4059 5.268E-05 0.7680 0.7680 0.000E+00 0.7440 0.7440 7.711E-03 0.5714 0.5791 2.590 25.083 1020092009 11 112009 5.060E-03 0.2286 0.2337 8.145E-04 0.0727 0.0735 4.233E-04 0.6843 0.6847 0.000E+00 0.6675 0.6675 1.064E-02 0.4953 0.5060 2.165 26.166 1120092009 12 122009 2.996E-03 0.4677 0.4707 4.754E-03 0.1851 0.1899 1.040E-02 0.4999 0.5103 9.846E-03 0.5118 0.5216 5.039E-06 0.7028 0.7028 2.395 27.364 1220092010 1 12010 1.211E-03 0.4737 0.4750 1.174E-03 0.4929 0.4940 4.156E-03 0.6118 0.6159 3.094E-03 0.6545 0.6576 6.551E-03 0.3914 0.3980 2.640 28.684 120102010 2 22010 3.040E-03 0.3685 0.3716 6.166E-04 0.4337 0.4343 4.975E-04 0.6939 0.6944 7.595E-04 0.2769 0.2777 3.432E-03 0.5827 0.5862 2.364 29.866 220102010 3 32010 4.350E-03 0.3924 0.3968 1.443E-03 0.4007 0.4021 1.343E-03 0.2978 0.2992 9.976E-03 0.5200 0.5300 8.293E-03 0.6813 0.6896 2.318 31.025 320102010 4 42010 3.638E-03 0.3257 0.3294 6.316E-03 0.2866 0.2929 1.391E-02 0.1131 0.1270 3.837E-03 0.6756 0.6795 4.194E-03 0.6900 0.6942 2.123 30.889 420102010 5 52010 1.210E-03 0.2160 0.2173 3.720E-03 0.3592 0.3630 8.433E-03 0.5402 0.5486 0.000E+00 0.7250 0.7250 9.263E-03 0.5549 0.5642 2.418 30.947 520102010 6 62010 1.368E-03 0.2752 0.2765 8.933E-05 0.1188 0.1189 1.592E-03 0.6418 0.6434 5.222E-05 0.6997 0.6998 0.000E+00 0.6795 0.6795 2.418 30.744 620102010 7 72010 4.674E-03 0.3028 0.3075 1.279E-02 0.1908 0.2036 1.133E-02 0.5992 0.6106 1.627E-03 0.7264 0.7280 2.984E-03 0.7195 0.7225 2.572 30.500 720102010 8 82010 1.063E-02 0.2730 0.2837 1.618E-03 0.4123 0.4139 1.194E-03 0.7075 0.7087 6.351E-03 0.6603 0.6666 1.141E-02 0.6051 0.6165 2.689 30.304 820102010 9 92010 1.343E-03 0.0339 0.0352 2.809E-03 0.3641 0.3669 4.178E-03 0.6506 0.6547 4.619E-03 0.6587 0.6634 1.706E-03 0.7229 0.7246 2.445 30.037 920102010 10 102010 6.227E-03 0.4231 0.4293 4.327E-03 0.1222 0.1265 5.130E-03 0.6454 0.6505 2.710E-03 0.7482 0.7509 3.533E-03 0.7524 0.7559 2.713 30.051 1020102010 11 112010 1.096E-03 0.4820 0.4831 7.432E-03 0.3458 0.3532 5.030E-04 0.7117 0.7122 3.892E-03 0.6542 0.6581 8.360E-04 0.1982 0.1990 2.406 30.024 1120102010 12 122010 1.469E-03 0.4881 0.4896 1.908E-03 0.4803 0.4822 1.038E-02 0.6596 0.6700 9.075E-03 0.7123 0.7213 0.000E+00 0.0000 0.0000 2.363 30.098 1220102011 1 12011 8.855E-04 0.4879 0.4887 1.755E-03 0.3521 0.3539 7.407E-03 0.5769 0.5843 8.379E-03 0.4891 0.4975 1.417E-02 0.5690 0.5831 2.508 29.799 120112011 2 22011 5.109E-03 0.1474 0.1525 4.671E-03 0.3380 0.3427 1.729E-03 0.6641 0.6659 2.244E-03 0.6085 0.6107 4.581E-06 0.6496 0.6496 2.421 29.670 220112011 3 32011 3.628E-03 0.3870 0.3906 7.554E-04 0.3904 0.3912 5.554E-03 0.6412 0.6468 6.157E-04 0.0848 0.0854 6.738E-03 0.6556 0.6623 2.176 29.723 320112011 4 42011 3.560E-03 0.3406 0.3442 3.441E-03 0.2429 0.2463 5.755E-03 0.6082 0.6139 1.696E-02 0.3618 0.3788 1.109E-04 0.7135 0.7136 2.297 29.812 420112011 5 52011 3.228E-03 0.2440 0.2473 2.647E-03 0.4120 0.4146 4.017E-03 0.3067 0.3107 1.559E-02 0.6065 0.6221 1.356E-02 0.6075 0.6210 2.216 29.686 520112011 6 62011 5.694E-03 0.3470 0.3527 1.059E-03 0.2418 0.2429 8.119E-03 0.6642 0.6723 7.318E-03 0.6235 0.6308 9.329E-03 0.6129 0.6222 2.521 29.517 620112011 7 72011 4.432E-03 0.3712 0.3756 3.749E-03 0.2634 0.2672 5.250E-03 0.6254 0.6307 0.000E+00 0.6696 0.6696 4.765E-03 0.6473 0.6520 2.595 29.282 720112011 8 82011 6.405E-03 0.1962 0.2026 4.492E-03 0.3927 0.3972 6.614E-03 0.5987 0.6054 7.168E-03 0.6413 0.6484 6.266E-03 0.6134 0.6197 2.473 29.110 820112011 9 92011 0.000E+00 0.0000 0.0000 4.169E-05 0.3785 0.3786 3.119E-03 0.6273 0.6304 7.788E-03 0.6281 0.6359 1.601E-02 0.5211 0.5371 2.182 29.005 920112011 10 102011 0.000E+00 0.0000 0.0000 4.381E-03 0.3438 0.3482 7.671E-03 0.5402 0.5479 5.089E-04 0.7004 0.7009 6.320E-03 0.6408 0.6471 2.244 28.832 1020112011 11 112011 1.194E-02 0.2158 0.2277 3.781E-03 0.2748 0.2786 4.836E-03 0.5955 0.6003 2.957E-03 0.6685 0.6715 1.223E-04 0.6770 0.6771 2.455 28.977 1120112011 12 122011 2.441E-03 0.4633 0.4657 6.391E-03 0.3873 0.3937 7.800E-03 0.6367 0.6445 1.629E-02 0.5435 0.5598 1.423E-03 0.2113 0.2127 2.276 28.917 1220112012 1 12012 4.584E-03 0.3987 0.4033 5.159E-03 0.4157 0.4209 1.005E-02 0.1892 0.1993 1.337E-03 0.6573 0.6586 9.985E-03 0.5534 0.5634 2.245 28.720 120122012 2 22012 7.804E-03 0.3946 0.4024 3.826E-03 0.4136 0.4174 1.652E-03 0.5952 0.5969 4.848E-03 0.0286 0.0334 1.691E-03 0.6034 0.6051 2.055 28.565 220122012 3 32012 3.562E-03 0.4133 0.4169 8.892E-04 0.4565 0.4574 1.202E-03 0.0434 0.0446 1.598E-03 0.6049 0.6065 1.265E-02 0.5062 0.5189 2.044 28.429 320122012 4 42012 3.645E-03 0.3585 0.3621 2.718E-03 0.4219 0.4247 0.000E+00 0.0000 0.0000 6.418E-03 0.5589 0.5653 1.696E-03 0.5461 0.5478 1.900 28.317 420122012 5 52012 7.470E-03 0.3787 0.3862 1.770E-03 0.4518 0.4536 1.186E-02 0.4090 0.4209 5.469E-03 0.5423 0.5478 1.082E-03 0.5556 0.5567 2.365 28.291 520122012 6 62012 3.089E-03 0.3843 0.3874 3.990E-03 0.2733 0.2773 4.421E-03 0.0551 0.0595 8.618E-03 0.4725 0.4811 1.831E-02 0.4475 0.4658 1.671 27.917 620122012 7 72012 4.337E-03 0.4095 0.4139 7.387E-03 0.4212 0.4286 1.924E-05 0.6693 0.6693 5.349E-03 0.6274 0.6327 2.428E-05 0.6610 0.6610 2.806 28.034 720122012 8 82012 6.178E-03 0.2188 0.2249 4.592E-03 0.3756 0.3802 1.374E-05 0.6166 0.6166 1.778E-03 0.4050 0.4068 9.340E-04 0.1010 0.1020 1.731 27.554 820122012 9 92012 5.728E-03 0.3637 0.3694 4.965E-03 0.2417 0.2466 4.432E-03 0.4623 0.4667 8.009E-03 0.3991 0.4071 9.072E-03 0.2822 0.2913 1.781 27.222 920122012 10 102012 9.598E-03 0.4606 0.4702 0.000E+00 0.0000 0.0000 8.841E-05 0.5786 0.5786 1.534E-02 0.6602 0.6755 1.257E-03 0.6437 0.6449 2.369 27.051 1020122012 11 112012 3.240E-03 0.2169 0.2201 3.918E-03 0.2240 0.2279 5.052E-03 0.6186 0.6236 4.581E-07 0.6515 0.6515 0.000E+00 0.6219 0.6219 2.345 27.020 112012

Total Methane

(tons/month)

Total Methane24-month

Rolling(tpy)

Month/ Year

Appendix 3j – Past Actual Methane Emissions



Emission FactorEmission Factor UnitsBtu Value of Fuel

Unit 5 Unit 6


of 1

Nitrous Oxide Fuel

Oil (tons/month

)

Nitrous Oxide Coal

(tons/month)

Nitrous Oxide Total (tons/month)

Nitrous Oxide Fuel

Oil (tons/month

)

Nitrous Oxide Coal

(tons/month)


Nitrous Oxide Fuel

Oil (tons/month

)

Nitrous Oxide Coal

(tons/month)

Nitrous Oxide Total (tons/month

)

Nitrous Oxide Fuel Oil

(tons/month)

Nitrous Oxide Coal (tons/month

)


Nitrous Oxide Fuel

Oil (tons/month)

Nitrous Oxide Coal

(tons/month)


1.32E-03 0.03 1.32E-03 0.03 1.32E-03 0.03 1.32E-03 0.03 1.32E-03 0.03lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton

138,500 138,500 138,500 138,500 138,500 2008 4 42008 1.466E-03 0.2944 0.2958 4.960E-04 0.3763 0.3768 0.000E+00 0.0000 0.0000 0.000E+00 0.5693 0.5693 0.000E+00 0.5490 0.5490 1.791 0.895 420082008 5 52008 8.783E-04 0.2241 0.2249 8.039E-04 0.3660 0.3668 2.788E-03 0.3480 0.3508 1.927E-03 0.4615 0.4634 3.169E-04 0.3009 0.3012 1.707 1.749 520082008 6 62008 4.428E-04 0.3436 0.3441 4.207E-04 0.3491 0.3495 0.000E+00 0.5551 0.5551 1.816E-03 0.4768 0.4786 4.198E-03 0.3684 0.3726 2.100 2.799 620082008 7 72008 1.099E-03 0.3113 0.3124 9.352E-04 0.3189 0.3198 0.000E+00 0.5586 0.5586 7.022E-04 0.5239 0.5246 6.630E-04 0.5695 0.5701 2.285 3.942 720082008 8 82008 2.199E-04 0.3882 0.3885 3.050E-04 0.3866 0.3869 2.675E-05 0.5558 0.5558 1.857E-03 0.4767 0.4785 2.455E-03 0.4853 0.4878 2.297 5.090 820082008 9 92008 1.238E-03 0.2737 0.2749 5.591E-04 0.3380 0.3385 0.000E+00 0.5290 0.5290 8.814E-05 0.5395 0.5395 5.497E-07 0.5477 0.5477 2.230 6.205 920082008 10 102008 1.505E-03 0.1168 0.1183 9.368E-04 0.2459 0.2468 2.053E-04 0.5718 0.5720 1.340E-03 0.4859 0.4872 0.000E+00 0.5781 0.5781 2.002 7.207 1020082008 11 112008 2.673E-04 0.3497 0.3500 2.277E-03 0.1942 0.1964 5.934E-03 0.4826 0.4885 3.763E-03 0.3888 0.3926 1.673E-04 0.3833 0.3834 1.811 8.112 1120082008 12 122008 8.253E-04 0.3662 0.3670 3.497E-04 0.3705 0.3708 3.704E-03 0.4090 0.4127 2.467E-03 0.4879 0.4903 0.000E+00 0.0000 0.0000 1.641 8.932 1220082009 1 12009 2.914E-04 0.3763 0.3766 7.066E-04 0.3960 0.3967 2.208E-05 0.5525 0.5525 1.391E-03 0.5177 0.5191 1.776E-03 0.4708 0.4726 2.317 10.091 120092009 2 22009 3.522E-04 0.2922 0.2925 3.130E-04 0.3029 0.3032 0.000E+00 0.4893 0.4893 8.046E-04 0.4251 0.4259 9.162E-07 0.4949 0.4949 2.006 11.094 220092009 3 32009 1.321E-03 0.2302 0.2316 3.258E-04 0.2866 0.2870 3.292E-04 0.4856 0.4859 0.000E+00 0.0000 0.0000 0.000E+00 0.5419 0.5419 1.546 11.867 320092009 4 42009 2.691E-04 0.2943 0.2946 2.233E-04 0.2912 0.2914 2.001E-03 0.0728 0.0748 1.564E-03 0.3979 0.3995 2.529E-05 0.5181 0.5181 1.578 12.656 420092009 5 52009 9.179E-04 0.3261 0.3270 3.405E-04 0.3200 0.3203 3.073E-03 0.3554 0.3584 3.588E-03 0.4117 0.4153 2.199E-03 0.3999 0.4021 1.823 13.568 520092009 6 62009 3.325E-04 0.3482 0.3486 1.277E-03 0.2882 0.2895 0.000E+00 0.5223 0.5223 0.000E+00 0.4897 0.4897 0.000E+00 0.4903 0.4903 2.140 14.638 620092009 7 72009 4.463E-04 0.3495 0.3500 3.772E-04 0.3693 0.3696 1.248E-04 0.5179 0.5180 0.000E+00 0.5256 0.5256 0.000E+00 0.5317 0.5317 2.295 15.786 720092009 8 82009 1.125E-03 0.2965 0.2976 2.804E-04 0.3855 0.3858 2.966E-03 0.4108 0.4138 9.679E-04 0.5031 0.5041 1.535E-03 0.4917 0.4933 2.095 16.833 820092009 9 92009 2.598E-04 0.0406 0.0409 2.540E-04 0.3736 0.3739 7.333E-04 0.4464 0.4471 3.969E-04 0.5033 0.5037 1.135E-03 0.4202 0.4214 1.787 17.726 920092009 10 102009 2.988E-03 0.0587 0.0616 6.782E-04 0.3019 0.3025 1.054E-05 0.5760 0.5760 0.000E+00 0.5580 0.5580 1.542E-03 0.4286 0.4301 1.928 18.690 1020092009 11 112009 1.012E-03 0.1715 0.1725 1.629E-04 0.0545 0.0547 8.465E-05 0.5132 0.5133 0.000E+00 0.5006 0.5006 2.128E-03 0.3715 0.3736 1.615 19.498 1120092009 12 122009 5.992E-04 0.3508 0.3514 9.508E-04 0.1388 0.1398 2.081E-03 0.3749 0.3770 1.969E-03 0.3839 0.3858 1.008E-06 0.5271 0.5271 1.781 20.388 1220092010 1 12010 2.422E-04 0.3553 0.3555 2.347E-04 0.3696 0.3699 8.312E-04 0.4588 0.4597 6.189E-04 0.4909 0.4915 1.310E-03 0.2936 0.2949 1.971 21.374 120102010 2 22010 6.081E-04 0.2764 0.2770 1.233E-04 0.3253 0.3254 9.950E-05 0.5205 0.5206 1.519E-04 0.2077 0.2078 6.864E-04 0.4370 0.4377 1.769 22.258 220102010 3 32010 8.700E-04 0.2943 0.2952 2.886E-04 0.3005 0.3008 2.685E-04 0.2234 0.2236 1.995E-03 0.3900 0.3920 1.659E-03 0.5110 0.5126 1.724 23.120 320102010 4 42010 7.275E-04 0.2443 0.2450 1.263E-03 0.2150 0.2162 2.783E-03 0.0848 0.0876 7.675E-04 0.5067 0.5075 8.388E-04 0.5175 0.5183 1.575 23.012 420102010 5 52010 2.421E-04 0.1620 0.1623 7.440E-04 0.2694 0.2702 1.687E-03 0.4051 0.4068 0.000E+00 0.5437 0.5437 1.853E-03 0.4162 0.4180 1.801 23.059 520102010 6 62010 2.737E-04 0.2064 0.2067 1.787E-05 0.0891 0.0891 3.184E-04 0.4814 0.4817 1.044E-05 0.5248 0.5248 0.000E+00 0.5096 0.5096 1.812 22.915 620102010 7 72010 9.348E-04 0.2271 0.2280 2.558E-03 0.1431 0.1457 2.267E-03 0.4494 0.4517 3.254E-04 0.5448 0.5451 5.968E-04 0.5397 0.5403 1.911 22.728 720102010 8 82010 2.125E-03 0.2048 0.2069 3.236E-04 0.3092 0.3095 2.388E-04 0.5306 0.5309 1.270E-03 0.4952 0.4965 2.282E-03 0.4538 0.4561 2.000 22.579 820102010 9 92010 2.685E-04 0.0254 0.0257 5.617E-04 0.2731 0.2736 8.356E-04 0.4879 0.4888 9.239E-04 0.4941 0.4950 3.412E-04 0.5422 0.5425 1.826 22.377 920102010 10 102010 1.245E-03 0.3173 0.3186 8.654E-04 0.0916 0.0925 1.026E-03 0.4840 0.4850 5.419E-04 0.5611 0.5617 7.066E-04 0.5643 0.5650 2.023 22.387 1020102010 11 112010 2.192E-04 0.3615 0.3617 1.486E-03 0.2593 0.2608 1.006E-04 0.5338 0.5339 7.784E-04 0.4907 0.4915 1.672E-04 0.1486 0.1488 1.797 22.380 1120102010 12 122010 2.938E-04 0.3661 0.3664 3.816E-04 0.3602 0.3606 2.075E-03 0.4947 0.4968 1.815E-03 0.5342 0.5360 0.000E+00 0.0000 0.0000 1.760 22.440 1220102011 1 12011 1.771E-04 0.3659 0.3661 3.511E-04 0.2641 0.2644 1.481E-03 0.4326 0.4341 1.676E-03 0.3669 0.3685 2.834E-03 0.4267 0.4296 1.863 22.212 120112011 2 22011 1.022E-03 0.1105 0.1116 9.342E-04 0.2535 0.2545 3.459E-04 0.4981 0.4985 4.488E-04 0.4564 0.4568 9.162E-07 0.4872 0.4872 1.808 22.114 220112011 3 32011 7.256E-04 0.2902 0.2909 1.511E-04 0.2928 0.2930 1.111E-03 0.4809 0.4820 1.231E-04 0.0636 0.0637 1.348E-03 0.4917 0.4930 1.623 22.152 320112011 4 42011 7.121E-04 0.2555 0.2562 6.881E-04 0.1821 0.1828 1.151E-03 0.4561 0.4573 3.392E-03 0.2714 0.2748 2.217E-05 0.5351 0.5351 1.706 22.216 420112011 5 52011 6.455E-04 0.1830 0.1837 5.294E-04 0.3090 0.3095 8.035E-04 0.2300 0.2308 3.119E-03 0.4549 0.4580 2.712E-03 0.4556 0.4583 1.640 22.124 520112011 6 62011 1.139E-03 0.2603 0.2614 2.118E-04 0.1814 0.1816 1.624E-03 0.4981 0.4998 1.464E-03 0.4676 0.4691 1.866E-03 0.4597 0.4615 1.873 21.991 620112011 7 72011 8.864E-04 0.2784 0.2793 7.499E-04 0.1976 0.1983 1.050E-03 0.4691 0.4701 0.000E+00 0.5022 0.5022 9.529E-04 0.4854 0.4864 1.936 21.811 720112011 8 82011 1.281E-03 0.1472 0.1485 8.985E-04 0.2945 0.2954 1.323E-03 0.4491 0.4504 1.434E-03 0.4809 0.4824 1.253E-03 0.4601 0.4613 1.838 21.683 820112011 9 92011 0.000E+00 0.0000 0.0000 8.337E-06 0.2839 0.2839 6.238E-04 0.4705 0.4711 1.558E-03 0.4711 0.4727 3.202E-03 0.3909 0.3941 1.622 21.601 920112011 10 102011 0.000E+00 0.0000 0.0000 8.761E-04 0.2579 0.2588 1.534E-03 0.4052 0.4067 1.018E-04 0.5253 0.5254 1.264E-03 0.4806 0.4818 1.673 21.473 1020112011 11 112011 2.387E-03 0.1618 0.1642 7.562E-04 0.2061 0.2069 9.672E-04 0.4466 0.4476 5.915E-04 0.5014 0.5020 2.446E-05 0.5077 0.5078 1.828 21.580 1120112011 12 122011 4.881E-04 0.3475 0.3479 1.278E-03 0.2905 0.2918 1.560E-03 0.4775 0.4791 3.258E-03 0.4076 0.4109 2.847E-04 0.1585 0.1588 1.688 21.533 1220112012 1 12012 9.167E-04 0.2990 0.3000 1.032E-03 0.3118 0.3128 2.009E-03 0.1419 0.1439 2.674E-04 0.4929 0.4932 1.997E-03 0.4151 0.4171 1.667 21.381 120122012 2 22012 1.561E-03 0.2960 0.2975 7.653E-04 0.3102 0.3110 3.304E-04 0.4464 0.4467 9.697E-04 0.0214 0.0224 3.383E-04 0.4526 0.4529 1.530 21.262 220122012 3 32012 7.124E-04 0.3100 0.3107 1.778E-04 0.3424 0.3426 2.403E-04 0.0325 0.0328 3.196E-04 0.4537 0.4540 2.530E-03 0.3797 0.3822 1.522 21.161 320122012 4 42012 7.289E-04 0.2688 0.2696 5.437E-04 0.3165 0.3170 0.000E+00 0.0000 0.0000 1.284E-03 0.4192 0.4205 3.392E-04 0.4095 0.4099 1.417 21.082 420122012 5 52012 1.494E-03 0.2840 0.2855 3.539E-04 0.3389 0.3392 2.371E-03 0.3068 0.3091 1.094E-03 0.4067 0.4078 2.163E-04 0.4167 0.4169 1.759 21.061 520122012 6 62012 6.178E-04 0.2882 0.2888 7.980E-04 0.2050 0.2058 8.843E-04 0.0413 0.0422 1.724E-03 0.3544 0.3561 3.662E-03 0.3356 0.3393 1.232 20.771 620122012 7 72012 8.674E-04 0.3071 0.3080 1.477E-03 0.3159 0.3174 3.848E-06 0.5020 0.5020 1.070E-03 0.4706 0.4716 4.856E-06 0.4957 0.4957 2.095 20.863 720122012 8 82012 1.236E-03 0.1641 0.1653 9.185E-04 0.2817 0.2826 2.749E-06 0.4625 0.4625 3.557E-04 0.3038 0.3041 1.868E-04 0.0758 0.0760 1.290 20.508 820122012 9 92012 1.146E-03 0.2728 0.2739 9.930E-04 0.1813 0.1823 8.863E-04 0.3467 0.3476 1.602E-03 0.2993 0.3009 1.814E-03 0.2117 0.2135 1.318 20.255 920122012 10 102012 1.920E-03 0.3454 0.3473 0.000E+00 0.0000 0.0000 1.768E-05 0.4339 0.4339 3.068E-03 0.4951 0.4982 2.515E-04 0.4827 0.4830 1.762 20.125 1020122012 11 112012 6.480E-04 0.1626 0.1633 7.837E-04 0.1680 0.1688 1.010E-03 0.4639 0.4649 9.162E-08 0.4886 0.4886 0.000E+00 0.4664 0.4664 1.752 20.102 112012

Total Nitrous Oxide

(tons/month)

Total Nitrous Oxide

24-month Rolling (tpy)

Month/ Year

Appendix 3k – Past Actual Nitrous Oxide Emissions


Emission FactorEmission Factor Units

Unit 9

Btu Value of Fuel

Unit 5 Unit 6 Unit 7 Unit 8


of 1

Lead Fuel Oil (tons/month)

Lead Coal (tons/month)

Lead Total (tons/month)



Lead Total (tons/month

)Lead Fuel Oil (tons/month)


Lead Total (tons/month

)

Lead Fuel Oil

(tons/month)






9.00E-06 0.00042 9.00E-06 0.00042 9.00E-06 0.00042 9.00E-06 0.00042 9.00E-06 0.00042lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton

138,500 138,500 138,500 138,500 138,500 2008 4 42008 9.974E-06 0.0041 0.0041 3.374E-06 0.0053 0.0053 0.000E+00 0.0000 0.0000 0.000E+00 0.0080 0.0080 0.000E+00 0.0077 0.0077 0.0251 0.0125 420082008 5 52008 5.975E-06 0.0031 0.0031 5.468E-06 0.0051 0.0051 1.897E-05 0.0049 0.0049 1.311E-05 0.0065 0.0065 2.156E-06 0.0042 0.0042 0.0239 0.0245 520082008 6 62008 3.012E-06 0.0048 0.0048 2.862E-06 0.0049 0.0049 0.000E+00 0.0078 0.0078 1.235E-05 0.0067 0.0067 2.856E-05 0.0052 0.0052 0.0293 0.0391 620082008 7 72008 7.476E-06 0.0044 0.0044 6.362E-06 0.0045 0.0045 0.000E+00 0.0078 0.0078 4.777E-06 0.0073 0.0073 4.510E-06 0.0080 0.0080 0.0320 0.0551 720082008 8 82008 1.496E-06 0.0054 0.0054 2.075E-06 0.0054 0.0054 1.820E-07 0.0078 0.0078 1.263E-05 0.0067 0.0067 1.670E-05 0.0068 0.0068 0.0321 0.0712 820082008 9 92008 8.421E-06 0.0038 0.0038 3.803E-06 0.0047 0.0047 0.000E+00 0.0074 0.0074 5.996E-07 0.0076 0.0076 3.740E-09 0.0077 0.0077 0.0312 0.0868 920082008 10 102008 1.024E-05 0.0016 0.0016 6.373E-06 0.0034 0.0034 1.397E-06 0.0080 0.0080 9.113E-06 0.0068 0.0068 0.000E+00 0.0081 0.0081 0.0280 0.1008 1020082008 11 112008 1.819E-06 0.0049 0.0049 1.549E-05 0.0027 0.0027 4.037E-05 0.0068 0.0068 2.560E-05 0.0054 0.0055 1.138E-06 0.0054 0.0054 0.0253 0.1134 1120082008 12 122008 5.614E-06 0.0051 0.0051 2.379E-06 0.0052 0.0052 2.519E-05 0.0057 0.0058 1.678E-05 0.0068 0.0068 0.000E+00 0.0000 0.0000 0.0229 0.1249 1220082009 1 12009 1.983E-06 0.0053 0.0053 4.807E-06 0.0055 0.0055 1.502E-07 0.0077 0.0077 9.463E-06 0.0072 0.0073 1.208E-05 0.0066 0.0066 0.0324 0.1411 120092009 2 22009 2.396E-06 0.0041 0.0041 2.129E-06 0.0042 0.0042 0.000E+00 0.0068 0.0068 5.473E-06 0.0060 0.0060 6.233E-09 0.0069 0.0069 0.0281 0.1551 220092009 3 32009 8.987E-06 0.0032 0.0032 2.216E-06 0.0040 0.0040 2.239E-06 0.0068 0.0068 0.000E+00 0.0000 0.0000 0.000E+00 0.0076 0.0076 0.0216 0.1659 320092009 4 42009 1.830E-06 0.0041 0.0041 1.519E-06 0.0041 0.0041 1.361E-05 0.0010 0.0010 1.064E-05 0.0056 0.0056 1.720E-07 0.0073 0.0073 0.0221 0.1770 420092009 5 52009 6.244E-06 0.0046 0.0046 2.316E-06 0.0045 0.0045 2.091E-05 0.0050 0.0050 2.441E-05 0.0058 0.0058 1.496E-05 0.0056 0.0056 0.0255 0.1897 520092009 6 62009 2.262E-06 0.0049 0.0049 8.686E-06 0.0040 0.0040 0.000E+00 0.0073 0.0073 0.000E+00 0.0069 0.0069 0.000E+00 0.0069 0.0069 0.0300 0.2047 620092009 7 72009 3.036E-06 0.0049 0.0049 2.566E-06 0.0052 0.0052 8.489E-07 0.0073 0.0073 0.000E+00 0.0074 0.0074 0.000E+00 0.0074 0.0074 0.0321 0.2207 720092009 8 82009 7.650E-06 0.0042 0.0042 1.908E-06 0.0054 0.0054 2.018E-05 0.0058 0.0058 6.585E-06 0.0070 0.0070 1.044E-05 0.0069 0.0069 0.0293 0.2354 820092009 9 92009 1.768E-06 0.0006 0.0006 1.728E-06 0.0052 0.0052 4.988E-06 0.0062 0.0063 2.700E-06 0.0070 0.0070 7.724E-06 0.0059 0.0059 0.0250 0.2479 920092009 10 102009 2.032E-05 0.0008 0.0008 4.614E-06 0.0042 0.0042 7.167E-08 0.0081 0.0081 0.000E+00 0.0078 0.0078 1.049E-05 0.0060 0.0060 0.0270 0.2613 1020092009 11 112009 6.884E-06 0.0024 0.0024 1.108E-06 0.0008 0.0008 5.759E-07 0.0072 0.0072 0.000E+00 0.0070 0.0070 1.448E-05 0.0052 0.0052 0.0226 0.2726 1120092009 12 122009 4.076E-06 0.0049 0.0049 6.468E-06 0.0019 0.0020 1.416E-05 0.0052 0.0053 1.340E-05 0.0054 0.0054 6.856E-09 0.0074 0.0074 0.0249 0.2851 1220092010 1 12010 1.648E-06 0.0050 0.0050 1.597E-06 0.0052 0.0052 5.654E-06 0.0064 0.0064 4.210E-06 0.0069 0.0069 8.912E-06 0.0041 0.0041 0.0276 0.2989 120102010 2 22010 4.137E-06 0.0039 0.0039 8.389E-07 0.0046 0.0046 6.768E-07 0.0073 0.0073 1.033E-06 0.0029 0.0029 4.669E-06 0.0061 0.0061 0.0247 0.3112 220102010 3 32010 5.918E-06 0.0041 0.0041 1.963E-06 0.0042 0.0042 1.827E-06 0.0031 0.0031 1.357E-05 0.0055 0.0055 1.128E-05 0.0072 0.0072 0.0241 0.3233 320102010 4 42010 4.949E-06 0.0034 0.0034 8.593E-06 0.0030 0.0030 1.893E-05 0.0012 0.0012 5.221E-06 0.0071 0.0071 5.706E-06 0.0072 0.0073 0.0220 0.3218 420102010 5 52010 1.647E-06 0.0023 0.0023 5.061E-06 0.0038 0.0038 1.147E-05 0.0057 0.0057 0.000E+00 0.0076 0.0076 1.260E-05 0.0058 0.0058 0.0252 0.3224 520102010 6 62010 1.862E-06 0.0029 0.0029 1.215E-07 0.0012 0.0012 2.166E-06 0.0067 0.0067 7.105E-08 0.0073 0.0073 0.000E+00 0.0071 0.0071 0.0254 0.3204 620102010 7 72010 6.359E-06 0.0032 0.0032 1.740E-05 0.0020 0.0020 1.542E-05 0.0063 0.0063 2.214E-06 0.0076 0.0076 4.060E-06 0.0076 0.0076 0.0267 0.3178 720102010 8 82010 1.446E-05 0.0029 0.0029 2.201E-06 0.0043 0.0043 1.624E-06 0.0074 0.0074 8.641E-06 0.0069 0.0069 1.552E-05 0.0064 0.0064 0.0280 0.3157 820102010 9 92010 1.827E-06 0.0004 0.0004 3.821E-06 0.0038 0.0038 5.684E-06 0.0068 0.0068 6.285E-06 0.0069 0.0069 2.321E-06 0.0076 0.0076 0.0255 0.3129 920102010 10 102010 8.472E-06 0.0044 0.0045 5.887E-06 0.0013 0.0013 6.979E-06 0.0068 0.0068 3.687E-06 0.0079 0.0079 4.807E-06 0.0079 0.0079 0.0283 0.3130 1020102010 11 112010 1.491E-06 0.0051 0.0051 1.011E-05 0.0036 0.0036 6.843E-07 0.0075 0.0075 5.295E-06 0.0069 0.0069 1.137E-06 0.0021 0.0021 0.0251 0.3130 1120102010 12 122010 1.999E-06 0.0051 0.0051 2.596E-06 0.0050 0.0050 1.412E-05 0.0069 0.0069 1.235E-05 0.0075 0.0075 0.000E+00 0.0000 0.0000 0.0246 0.3138 1220102011 1 12011 1.205E-06 0.0051 0.0051 2.388E-06 0.0037 0.0037 1.008E-05 0.0061 0.0061 1.140E-05 0.0051 0.0051 1.928E-05 0.0060 0.0060 0.0260 0.3106 120112011 2 22011 6.950E-06 0.0015 0.0016 6.355E-06 0.0035 0.0036 2.353E-06 0.0070 0.0070 3.053E-06 0.0064 0.0064 6.233E-09 0.0068 0.0068 0.0253 0.3092 220112011 3 32011 4.936E-06 0.0041 0.0041 1.028E-06 0.0041 0.0041 7.556E-06 0.0067 0.0067 8.376E-07 0.0009 0.0009 9.168E-06 0.0069 0.0069 0.0227 0.3098 320112011 4 42011 4.844E-06 0.0036 0.0036 4.681E-06 0.0026 0.0026 7.831E-06 0.0064 0.0064 2.308E-05 0.0038 0.0038 1.508E-07 0.0075 0.0075 0.0238 0.3106 420112011 5 52011 4.391E-06 0.0026 0.0026 3.601E-06 0.0043 0.0043 5.466E-06 0.0032 0.0032 2.122E-05 0.0064 0.0064 1.845E-05 0.0064 0.0064 0.0229 0.3094 520112011 6 62011 7.747E-06 0.0036 0.0037 1.441E-06 0.0025 0.0025 1.105E-05 0.0070 0.0070 9.956E-06 0.0065 0.0066 1.269E-05 0.0064 0.0064 0.0262 0.3075 620112011 7 72011 6.030E-06 0.0039 0.0039 5.101E-06 0.0028 0.0028 7.143E-06 0.0066 0.0066 0.000E+00 0.0070 0.0070 6.482E-06 0.0068 0.0068 0.0271 0.3050 720112011 8 82011 8.715E-06 0.0021 0.0021 6.112E-06 0.0041 0.0041 8.999E-06 0.0063 0.0063 9.752E-06 0.0067 0.0067 8.525E-06 0.0064 0.0064 0.0257 0.3032 820112011 9 92011 0.000E+00 0.0000 0.0000 5.672E-08 0.0040 0.0040 4.244E-06 0.0066 0.0066 1.060E-05 0.0066 0.0066 2.178E-05 0.0055 0.0055 0.0227 0.3020 920112011 10 102011 0.000E+00 0.0000 0.0000 5.960E-06 0.0036 0.0036 1.044E-05 0.0057 0.0057 6.924E-07 0.0074 0.0074 8.598E-06 0.0067 0.0067 0.0234 0.3002 1020112011 11 112011 1.624E-05 0.0023 0.0023 5.144E-06 0.0029 0.0029 6.580E-06 0.0063 0.0063 4.024E-06 0.0070 0.0070 1.664E-07 0.0071 0.0071 0.0256 0.3017 1120112011 12 122011 3.321E-06 0.0049 0.0049 8.696E-06 0.0041 0.0041 1.061E-05 0.0067 0.0067 2.216E-05 0.0057 0.0057 1.936E-06 0.0022 0.0022 0.0236 0.3011 1220112012 1 12012 6.236E-06 0.0042 0.0042 7.019E-06 0.0044 0.0044 1.367E-05 0.0020 0.0020 1.819E-06 0.0069 0.0069 1.358E-05 0.0058 0.0058 0.0233 0.2989 120122012 2 22012 1.062E-05 0.0041 0.0042 5.206E-06 0.0043 0.0043 2.247E-06 0.0062 0.0063 6.596E-06 0.0003 0.0003 2.301E-06 0.0063 0.0063 0.0214 0.2972 220122012 3 32012 4.846E-06 0.0043 0.0043 1.210E-06 0.0048 0.0048 1.635E-06 0.0005 0.0005 2.174E-06 0.0064 0.0064 1.721E-05 0.0053 0.0053 0.0213 0.2958 320122012 4 42012 4.959E-06 0.0038 0.0038 3.698E-06 0.0044 0.0044 0.000E+00 0.0000 0.0000 8.732E-06 0.0059 0.0059 2.307E-06 0.0057 0.0057 0.0198 0.2947 420122012 5 52012 1.016E-05 0.0040 0.0040 2.408E-06 0.0047 0.0047 1.613E-05 0.0043 0.0043 7.440E-06 0.0057 0.0057 1.471E-06 0.0058 0.0058 0.0246 0.2944 520122012 6 62012 4.203E-06 0.0040 0.0040 5.429E-06 0.0029 0.0029 6.016E-06 0.0006 0.0006 1.173E-05 0.0050 0.0050 2.491E-05 0.0047 0.0047 0.0172 0.2904 620122012 7 72012 5.901E-06 0.0043 0.0043 1.005E-05 0.0044 0.0044 2.618E-08 0.0070 0.0070 7.277E-06 0.0066 0.0066 3.303E-08 0.0069 0.0069 0.0293 0.2917 720122012 8 82012 8.406E-06 0.0023 0.0023 6.248E-06 0.0039 0.0040 1.870E-08 0.0065 0.0065 2.419E-06 0.0043 0.0043 1.271E-06 0.0011 0.0011 0.0180 0.2867 820122012 9 92012 7.793E-06 0.0038 0.0038 6.755E-06 0.0025 0.0025 6.029E-06 0.0049 0.0049 1.090E-05 0.0042 0.0042 1.234E-05 0.0030 0.0030 0.0184 0.2831 920122012 10 102012 1.306E-05 0.0048 0.0048 0.000E+00 0.0000 0.0000 1.203E-07 0.0061 0.0061 2.087E-05 0.0069 0.0070 1.711E-06 0.0068 0.0068 0.0246 0.2813 1020122012 11 112012 4.408E-06 0.0023 0.0023 5.331E-06 0.0024 0.0024 6.873E-06 0.0065 0.0065 6.233E-10 0.0068 0.0068 0.000E+00 0.0065 0.0065 0.0245 0.2810 112012

Month/ Year

Total Lead24-month

Rolling (tpy)

Total Lead (tons/month)

Appendix 3l – Past Actual Lead Emissions





of 1

HF Fuel Oil (tons/month)

HF Coal (tons/month

)

HF Total (tons/month

)HF Fuel Oil

(tons/month)HF Coal

(tons/month)

HF Total (tons/month

)HF Fuel Oil

(tons/month)HF Coal

(tons/month)HF Total

(tons/month)HF Fuel Oil

(tons/month)

HF Coal (tons/month

)HF Total

(tons/month)HF Fuel Oil

(tons/month)HF Coal

(tons/month)HF Total

(tons/month)- 0.15 - 0.15 - 0.15 - 0.15 - 0.15

lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton 138,500 138,500 138,500 138,500 138,500

2008 4 42008 0 1.472 1.472 0 1.881 1.881 0 0.000 0.000 0 2.846 2.846 0 2.745 2.745 8.945 4.472 420082008 5 52008 0 1.120 1.120 0 1.830 1.830 0 1.740 1.740 0 2.308 2.308 0 1.505 1.505 8.502 8.723 520082008 6 62008 0 1.718 1.718 0 1.746 1.746 0 2.776 2.776 0 2.384 2.384 0 1.842 1.842 10.465 13.96 620082008 7 72008 0 1.556 1.556 0 1.594 1.594 0 2.793 2.793 0 2.619 2.619 0 2.847 2.847 11.411 19.66 720082008 8 82008 0 1.941 1.941 0 1.933 1.933 0 2.779 2.779 0 2.383 2.383 0 2.426 2.426 11.463 25.39 820082008 9 92008 0 1.368 1.368 0 1.690 1.690 0 2.645 2.645 0 2.697 2.697 0 2.739 2.739 11.139 30.96 920082008 10 102008 0 0.584 0.584 0 1.229 1.229 0 2.859 2.859 0 2.430 2.430 0 2.891 2.891 9.992 35.96 1020082008 11 112008 0 1.749 1.749 0 0.971 0.971 0 2.413 2.413 0 1.944 1.944 0 1.916 1.916 8.993 40.45 1120082008 12 122008 0 1.831 1.831 0 1.852 1.852 0 2.045 2.045 0 2.439 2.439 0 0.000 0.000 8.167 44.54 1220082009 1 12009 0 1.882 1.882 0 1.980 1.980 0 2.762 2.762 0 2.588 2.588 0 2.354 2.354 11.566 50.32 120092009 2 22009 0 1.461 1.461 0 1.514 1.514 0 2.446 2.446 0 2.126 2.126 0 2.475 2.475 10.022 55.33 220092009 3 32009 0 1.151 1.151 0 1.433 1.433 0 2.428 2.428 0 0.000 0.000 0 2.710 2.710 7.722 59.19 320092009 4 42009 0 1.472 1.472 0 1.456 1.456 0 0.364 0.364 0 1.989 1.989 0 2.591 2.591 7.871 63.13 420092009 5 52009 0 1.631 1.631 0 1.600 1.600 0 1.777 1.777 0 2.059 2.059 0 1.999 1.999 9.065 67.66 520092009 6 62009 0 1.741 1.741 0 1.441 1.441 0 2.611 2.611 0 2.448 2.448 0 2.451 2.451 10.693 73.01 620092009 7 72009 0 1.748 1.748 0 1.846 1.846 0 2.589 2.589 0 2.628 2.628 0 2.659 2.659 11.470 78.74 720092009 8 82009 0 1.483 1.483 0 1.928 1.928 0 2.054 2.054 0 2.516 2.516 0 2.459 2.459 10.438 83.96 820092009 9 92009 0 0.203 0.203 0 1.868 1.868 0 2.232 2.232 0 2.517 2.517 0 2.101 2.101 8.921 88.42 920092009 10 102009 0 0.293 0.293 0 1.509 1.509 0 2.880 2.880 0 2.790 2.790 0 2.143 2.143 9.615 93.23 1020092009 11 112009 0 0.857 0.857 0 0.273 0.273 0 2.566 2.566 0 2.503 2.503 0 1.857 1.857 8.057 97.26 1120092009 12 122009 0 1.754 1.754 0 0.694 0.694 0 1.875 1.875 0 1.919 1.919 0 2.635 2.635 8.877 101.7 1220092010 1 12010 0 1.777 1.777 0 1.848 1.848 0 2.294 2.294 0 2.454 2.454 0 1.468 1.468 9.841 106.6 120102010 2 22010 0 1.382 1.382 0 1.626 1.626 0 2.602 2.602 0 1.038 1.038 0 2.185 2.185 8.834 111.0 220102010 3 32010 0 1.472 1.472 0 1.502 1.502 0 1.117 1.117 0 1.950 1.950 0 2.555 2.555 8.596 115.3 320102010 4 42010 0 1.221 1.221 0 1.075 1.075 0 0.424 0.424 0 2.534 2.534 0 2.588 2.588 7.841 114.8 420102010 5 52010 0 0.810 0.810 0 1.347 1.347 0 2.026 2.026 0 2.719 2.719 0 2.081 2.081 8.982 115.0 520102010 6 62010 0 1.032 1.032 0 0.446 0.446 0 2.407 2.407 0 2.624 2.624 0 2.548 2.548 9.056 114.3 620102010 7 72010 0 1.136 1.136 0 0.716 0.716 0 2.247 2.247 0 2.724 2.724 0 2.698 2.698 9.521 113.4 720102010 8 82010 0 1.024 1.024 0 1.546 1.546 0 2.653 2.653 0 2.476 2.476 0 2.269 2.269 9.968 112.6 820102010 9 92010 0 0.127 0.127 0 1.365 1.365 0 2.440 2.440 0 2.470 2.470 0 2.711 2.711 9.113 111.6 920102010 10 102010 0 1.587 1.587 0 0.458 0.458 0 2.420 2.420 0 2.806 2.806 0 2.822 2.822 10.092 111.7 1020102010 11 112010 0 1.807 1.807 0 1.297 1.297 0 2.669 2.669 0 2.453 2.453 0 0.743 0.743 8.969 111.7 1120102010 12 122010 0 1.830 1.830 0 1.801 1.801 0 2.474 2.474 0 2.671 2.671 0 0.000 0.000 8.776 112.0 1220102011 1 12011 0 1.829 1.829 0 1.320 1.320 0 2.163 2.163 0 1.834 1.834 0 2.134 2.134 9.281 110.8 120112011 2 22011 0 0.553 0.553 0 1.268 1.268 0 2.491 2.491 0 2.282 2.282 0 2.436 2.436 9.029 110.3 220112011 3 32011 0 1.451 1.451 0 1.464 1.464 0 2.405 2.405 0 0.318 0.318 0 2.458 2.458 8.096 110.5 320112011 4 42011 0 1.277 1.277 0 0.911 0.911 0 2.281 2.281 0 1.357 1.357 0 2.675 2.675 8.501 110.8 420112011 5 52011 0 0.915 0.915 0 1.545 1.545 0 1.150 1.150 0 2.274 2.274 0 2.278 2.278 8.163 110.4 520112011 6 62011 0 1.301 1.301 0 0.907 0.907 0 2.491 2.491 0 2.338 2.338 0 2.298 2.298 9.335 109.7 620112011 7 72011 0 1.392 1.392 0 0.988 0.988 0 2.345 2.345 0 2.511 2.511 0 2.427 2.427 9.663 108.8 720112011 8 82011 0 0.736 0.736 0 1.472 1.472 0 2.245 2.245 0 2.405 2.405 0 2.300 2.300 9.159 108.1 820112011 9 92011 0 0.000 0.000 0 1.420 1.420 0 2.352 2.352 0 2.356 2.356 0 1.954 1.954 8.082 107.7 920112011 10 102011 0 0.000 0.000 0 1.289 1.289 0 2.026 2.026 0 2.627 2.627 0 2.403 2.403 8.345 107.1 1020112011 11 112011 0 0.809 0.809 0 1.031 1.031 0 2.233 2.233 0 2.507 2.507 0 2.539 2.539 9.118 107.6 1120112011 12 122011 0 1.737 1.737 0 1.452 1.452 0 2.388 2.388 0 2.038 2.038 0 0.792 0.792 8.408 107.4 1220112012 1 12012 0 1.495 1.495 0 1.559 1.559 0 0.710 0.710 0 2.465 2.465 0 2.075 2.075 8.304 106.6 120122012 2 22012 0 1.480 1.480 0 1.551 1.551 0 2.232 2.232 0 0.107 0.107 0 2.263 2.263 7.633 106.0 220122012 3 32012 0 1.550 1.550 0 1.712 1.712 0 0.163 0.163 0 2.268 2.268 0 1.898 1.898 7.591 105.5 320122012 4 42012 0 1.344 1.344 0 1.582 1.582 0 0.000 0.000 0 2.096 2.096 0 2.048 2.048 7.070 105.1 420122012 5 52012 0 1.420 1.420 0 1.694 1.694 0 1.534 1.534 0 2.034 2.034 0 2.083 2.083 8.765 105.0 520122012 6 62012 0 1.441 1.441 0 1.025 1.025 0 0.207 0.207 0 1.772 1.772 0 1.678 1.678 6.123 103.6 620122012 7 72012 0 1.536 1.536 0 1.580 1.580 0 2.510 2.510 0 2.353 2.353 0 2.479 2.479 10.457 104.0 720122012 8 82012 0 0.820 0.820 0 1.409 1.409 0 2.312 2.312 0 1.519 1.519 0 0.379 0.379 6.439 102.3 820122012 9 92012 0 1.364 1.364 0 0.906 0.906 0 1.733 1.733 0 1.496 1.496 0 1.058 1.058 6.558 101.0 920122012 10 102012 0 1.727 1.727 0 0.000 0.000 0 2.170 2.170 0 2.476 2.476 0 2.414 2.414 8.786 100.3 1020122012 11 112012 0 0.813 0.813 0 0.840 0.840 0 2.320 2.320 0 2.443 2.443 0 2.332 2.332 8.748 100.2 112012

Month/ Year

Total HF (tons/month)

Total HF 24-month

Rolling (tpy)

Appendix 3m – Past Actual HF Emissions





of 1

H2SO4 Fuel Oil

(tons/month)H2SO4 Coal (tons/month)

H2SO4 Total (tons/month)

H2SO4 Fuel Oil



H2SO4 Fuel Oil



H2SO4 Fuel Oil



H2SO4 Fuel Oil

(tons/month)

H2SO4 Coal (tons/month

)

H2SO4 Total (tons/month

)- 0.00858 - 0.00858 - 0.00858 - 0.00858 - 0.00858

lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton lb/MMBtu lbs/ton 138,500 138,500 138,500 138,500 138,500

2008 4 42008 0 0.0004 0.0004 0 0.9862 0.9862 0 0.0000 0.0000 0 0.8851 0.8851 0 0.8536 0.8536 2.725 1.363 420082008 5 52008 0 0.0003 0.0003 0 0.9440 0.9440 0 0.5375 0.5375 0 0.7145 0.7145 0 0.4674 0.4674 2.664 2.695 520082008 6 62008 0 0.0004 0.0004 0 0.8971 0.8971 0 0.8574 0.8574 0 0.7349 0.7349 0 0.5679 0.5679 3.058 4.223 620082008 7 72008 0 0.0004 0.0004 0 0.8254 0.8254 0 0.8627 0.8627 0 0.8009 0.8009 0 0.8701 0.8701 3.360 5.903 720082008 8 82008 0 0.0005 0.0005 0 1.0168 1.0168 0 0.8583 0.8583 0 1.0107 1.0107 0 0.9783 0.9783 3.865 7.835 820082008 9 92008 0 0.0004 0.0004 0 0.8957 0.8957 0 1.1195 1.1195 0 1.1333 1.1333 0 1.1518 1.1518 4.301 9.986 920082008 10 102008 0 0.0002 0.0002 0 0.6554 0.6554 0 1.0466 1.0466 0 0.8818 0.8818 0 1.0561 1.0561 3.640 11.81 1020082008 11 112008 0 0.0005 0.0005 0 0.5236 0.5236 0 0.8005 0.8005 0 0.6487 0.6487 0 0.6419 0.6419 2.615 13.11 1120082008 12 122008 0 0.0005 0.0005 0 1.0101 1.0101 0 0.6550 0.6550 0 0.7778 0.7778 0 0.0000 0.0000 2.443 14.34 1220082009 1 12009 0 0.0005 0.0005 0 1.1100 1.1100 0 0.8848 0.8848 0 0.8291 0.8291 0 0.7540 0.7540 3.578 16.12 120092009 2 22009 0 0.0004 0.0004 0 0.8490 0.8490 0 0.7836 0.7836 0 0.6808 0.6808 0 0.7927 0.7927 3.106 17.68 220092009 3 32009 0 0.0003 0.0003 0 0.8034 0.8034 0 0.7777 0.7777 0 0.0000 0.0000 0 0.8680 0.8680 2.449 18.90 320092009 4 42009 0 0.0004 0.0004 0 0.7994 0.7994 0 0.1125 0.1125 0 0.6145 0.6145 0 0.8002 0.8002 2.327 20.07 420092009 5 52009 0 0.0004 0.0004 0 0.8785 0.8785 0 0.5488 0.5488 0 0.6359 0.6359 0 0.6176 0.6176 2.681 21.41 520092009 6 62009 0 0.0005 0.0005 0 0.7912 0.7912 0 0.8066 0.8066 0 0.7563 0.7563 0 0.7572 0.7572 3.112 22.96 620092009 7 72009 0 0.0005 0.0005 0 1.0138 1.0138 0 0.7998 0.7998 0 0.8117 0.8117 0 0.8212 0.8212 3.447 24.69 720092009 8 82009 0 0.0004 0.0004 0 1.0585 1.0585 0 0.6345 0.6345 0 0.7770 0.7770 0 0.7594 0.7594 3.230 26.30 820092009 9 92009 0 0.0001 0.0001 0 1.0258 1.0258 0 0.6894 0.6894 0 0.7773 0.7773 0 0.6490 0.6490 3.142 27.87 920092009 10 102009 0 0.0001 0.0001 0 0.8461 0.8461 0 0.8566 0.8566 0 0.8298 0.8298 0 0.6373 0.6373 3.170 29.46 1020092009 11 112009 0 0.0002 0.0002 0 0.1528 0.1528 0 0.7633 0.7633 0 0.7445 0.7445 0 0.5525 0.5525 2.213 30.56 1120092009 12 122009 0 0.0005 0.0005 0 0.3891 0.3891 0 0.5576 0.5576 0 0.5709 0.5709 0 0.7839 0.7839 2.302 31.71 1220092010 1 12010 0 0.0005 0.0005 0 1.0360 1.0360 0 0.6824 0.6824 0 0.7300 0.7300 0 0.4366 0.4366 2.885 33.16 120102010 2 22010 0 0.0004 0.0004 0 0.9117 0.9117 0 0.7740 0.7740 0 0.3089 0.3089 0 0.6500 0.6500 2.645 34.48 220102010 3 32010 0 0.0004 0.0004 0 0.8422 0.8422 0 0.3322 0.3322 0 0.6023 0.6023 0 0.7891 0.7891 2.566 35.76 320102010 4 42010 0 0.0003 0.0003 0 0.6025 0.6025 0 0.1456 0.1456 0 0.8985 0.8985 0 0.9176 0.9176 2.564 35.68 420102010 5 52010 0 0.0002 0.0002 0 0.7243 0.7243 0 0.6488 0.6488 0 0.8708 0.8708 0 0.6666 0.6666 2.911 35.81 520102010 6 62010 0 0.0003 0.0003 0 0.2395 0.2395 0 0.7434 0.7434 0 0.8105 0.8105 0 0.7871 0.7871 2.581 35.57 620102010 7 72010 0 0.0003 0.0003 0 0.3848 0.3848 0 0.6684 0.6684 0 0.8102 0.8102 0 0.8026 0.8026 2.666 35.22 720102010 8 82010 0 0.0003 0.0003 0 0.8313 0.8313 0 0.7891 0.7891 0 0.7365 0.7365 0 0.6749 0.6749 3.032 34.80 820102010 9 92010 0 0.0000 0.0000 0 0.7341 0.7341 0 0.7256 0.7256 0 0.7348 0.7348 0 0.8063 0.8063 3.001 34.15 920102010 10 102010 0 0.0004 0.0004 0 0.2464 0.2464 0 0.6921 0.6921 0 0.8024 0.8024 0 0.8069 0.8069 2.548 33.61 1020102010 11 112010 0 0.0005 0.0005 0 0.6972 0.6972 0 0.7633 0.7633 0 0.7017 0.7017 0 0.2125 0.2125 2.375 33.49 1120102010 12 122010 0 0.0005 0.0005 0 0.9685 0.9685 0 0.7075 0.7075 0 0.7639 0.7639 0 0.0000 0.0000 2.440 33.49 1220102011 1 12011 0 0.3760 0.3760 0 0.5059 0.5059 0 0.6187 0.6187 0 0.5246 0.5246 0 0.6102 0.6102 2.635 33.02 120112011 2 22011 0 0.1363 0.1363 0 0.3910 0.3910 0 0.7123 0.7123 0 0.6526 0.6526 0 0.6967 0.6967 2.589 32.76 220112011 3 32011 0 0.0004 0.0004 0 0.7872 0.7872 0 0.6877 0.6877 0 0.0909 0.0909 0 0.7031 0.7031 2.269 32.67 320112011 4 42011 0 0.0003 0.0003 0 0.4897 0.4897 0 0.6523 0.6523 0 0.3881 0.3881 0 0.7652 0.7652 2.296 32.65 420112011 5 52011 0 0.0002 0.0002 0 0.8307 0.8307 0 0.3421 0.3421 0 0.6765 0.6765 0 0.6776 0.6776 2.527 32.57 520112011 6 62011 0 0.0003 0.0003 0 0.4876 0.4876 0 0.7408 0.7408 0 0.6955 0.6955 0 0.6836 0.6836 2.608 32.32 620112011 7 72011 0 0.0435 0.0435 0 0.5424 0.5424 0 1.1268 1.1268 0 1.1491 1.1491 0 1.1662 1.1662 4.028 32.61 720112011 8 82011 0 0.0002 0.0002 0 0.8086 0.8086 0 0.6678 0.6678 0 0.7153 0.7153 0 0.6842 0.6842 2.876 32.44 820112011 9 92011 0 0.0000 0.0000 0 0.7308 0.7308 0 0.6997 0.6997 0 0.7006 0.7006 0 0.5813 0.5813 2.712 32.22 920112011 10 102011 0 0.0000 0.0000 0 0.6638 0.6638 0 0.6026 0.6026 0 0.7812 0.7812 0 0.7147 0.7147 2.762 32.02 1020112011 11 112011 0 0.2407 0.2407 0 0.3538 0.3538 0 0.6642 0.6642 0 0.7456 0.7456 0 0.7551 0.7551 2.759 32.29 1120112011 12 122011 0 0.5167 0.5167 0 0.4320 0.4320 0 0.7102 0.7102 0 0.6062 0.6062 0 0.2357 0.2357 2.501 32.39 1220112012 1 12012 0 0.4447 0.4447 0 0.4637 0.4637 0 0.2111 0.2111 0 0.7331 0.7331 0 0.6173 0.6173 2.470 32.18 120122012 2 22012 0 0.4401 0.4401 0 0.4613 0.4613 0 0.6639 0.6639 0 0.0319 0.0319 0 0.6730 0.6730 2.270 31.99 220122012 3 32012 0 0.4610 0.4610 0 0.5092 0.5092 0 0.0484 0.0484 0 0.6747 0.6747 0 0.5646 0.5646 2.258 31.84 320122012 4 42012 0 0.3998 0.3998 0 0.4706 0.4706 0 0.0000 0.0000 0 0.6234 0.6234 0 0.6091 0.6091 2.103 31.61 420122012 5 52012 0 0.4224 0.4224 0 0.5040 0.5040 0 0.4562 0.4562 0 0.6049 0.6049 0 0.6197 0.6197 2.607 31.46 520122012 6 62012 0 0.4286 0.4286 0 0.3049 0.3049 0 0.0615 0.0615 0 0.5270 0.5270 0 0.4992 0.4992 1.821 31.08 620122012 7 72012 0 0.4568 0.4568 0 0.4699 0.4699 0 0.7465 0.7465 0 0.6998 0.6998 0 0.7373 0.7373 3.110 31.30 720122012 8 82012 0 0.2440 0.2440 0 0.4190 0.4190 0 0.6878 0.6878 0 0.4517 0.4517 0 0.1127 0.1127 1.915 30.74 820122012 9 92012 0 0.4057 0.4057 0 0.2696 0.2696 0 0.5156 0.5156 0 0.4451 0.4451 0 0.3148 0.3148 1.951 30.22 920122012 10 102012 0 0.5137 0.5137 0 0.0000 0.0000 0 0.6453 0.6453 0 0.7364 0.7364 0 0.7179 0.7179 2.613 30.25 1020122012 11 112012 0 0.2419 0.2419 0 0.2498 0.2498 0 0.6899 0.6899 0 0.7267 0.7267 0 0.6936 0.6936 2.602 30.36 112012

Month/ Year

Total H2SO4

24-month Rolling (tpy)

Total H2SO4

(tons/month)

Appendix 3n – Past Actual Sulfuric Acid Emissions



Month

Unit 8 Unit 9



Appendix 4

Z:\2012\120697\WORK\REPT\PTI APPLICATION\APP_4_PROMOD.DOCX

Appendix 4 – Projected Utilization Air Use Permit to Install AQCS Retrofit PIPP We Energies, Marquette, Michigan

Following is the PROMOD run data,2013-01-21 PIPP 2022 Projected Operation: PROJECTED PI 5-9 FUEL CONSUMPTION: 2013-2017 & 2022 J:\DATA\WF\Power Marketing & Planning\Planning\Misc\20130110-PI_MaxOutput-2022\[PI_2013-2017.xlsx]Sheet23

2013 2014 2015 2016 2017

2022

Projected "50/50" fuel burn - million MBtu/year 22.9 23.5 23.6 23.6 23.6

25.9

Projected "50/50" fuel burn MBtu/year with PI 5 & 6 capacity @ 88 MW - million MBtu/year

31.1

High limit based PI 5 & 6 at 88 MW and the highest actual EAF-adjusted 12 month capacity factor experienced since 1990. - million MBtu/year

35.1

Projected coal burn is for PI 5-9 total plant (WE + Wolverine)

Appendix 5

Appendix 5 - Projected Annual Actual Emissions for ProjectAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Projected Heat Input for All Boilers 35,100,000 MMBtu/yr

Projected Heat Input Capacity 6,292,131 MMBtu/yr 6,485,399 MMBtu/yr 7,093,863 MMBtu/yr 7,524,686 MMBtu/yr 7,703,920 MMBtu/yrHigher heating Value 23.5 MMBtu/ton 23.5 MMBtu/ton 18.5 MMBtu/ton 18.5 MMBtu/ton 18.5 MMBtu/ton

Throughput 267,750 ton/yr 275,974 ton/yr 383,452 ton/yr 406,740 ton/yr 416,428 ton/yrSulfur Content 0.9 wt% 0.9 wt% 0.9 wt% 0.9 wt% 0.9 wt%

Projected Condensable Control 0.8 wt% 0.8 wt% 0.8 wt% 0.6 wt% 0.6 wt%Projected

Actual Emissions

(tpy)

Projected Actual

Emissions(tpy)

Projected Actual

Emissions(tpy)

Projected Actual

Emissions(tpy)

Projected Actual

Emissions(tpy)

Criteria PollutantsCO 630-08-0 0.20 lb/Million Btus 629 0.20 lb/Million Btus 649 0.20 lb/Million Btus 709 0.20 lb/Million Btus 752 0.20 lb/Million Btus 770 3,510NOX 0.25 lb/Million Btus 787 0.25 lb/Million Btus 811 0.25 lb/Million Btus 887 0.25 lb/Million Btus 941 0.25 lb/Million Btus 963 4,388PM, filterable 0.0073 lb/Million Btus 23.0 0.0073 lb/Million Btus 24 0.0073 lb/Million Btus 26 0.0073 lb/Million Btus 27 0.0073 lb/Million Btus 28 128PM10, total (filterable+condensable) 0.014 lb/Million Btus 44.0 0.014 lb/Million Btus 45.4 0.014 lb/Million Btus 49.7 0.026 lb/Million Btus 97.8 0.026 lb/Million Btus 100.2 337PM2.5, total (filterable+condensable) 0.014 lb/Million Btus 44.0 0.014 lb/Million Btus 45.4 0.014 lb/Million Btus 49.7 0.026 lb/Million Btus 97.8 0.026 lb/Million Btus 100.2 337SO2 2025-88-4 0.08 lb/Million Btus 252 0.08 lb/Million Btus 259 0.08 lb/Million Btus 284 0.45 lb/Million Btus 1,693 0.45 lb/Million Btus 1,733 4,221VOC 0.06 lb/Tons 8.0 0.06 lb/Tons 8.3 0.06 lb/Tons 11.5 0.06 lb/Tons 12.2 0.06 lb/Tons 12.5 52.5Greenhouse Gas EmissionsCO2 124-38-9 207.0 lb/Million Btus 651,236 207.0 lb/Million Btus 671,239 207.0 lb/Million Btus 734,215 207.0 lb/Million Btus 778,805 207.0 lb/Million Btus 797,356 3,632,850CH4 74-82-8 0.024 lb/Million Btus 76.3 0.024 lb/Million Btus 78.6 0.024 lb/Million Btus 86.0 0.024 lb/Million Btus 91.2 0.024 lb/Million Btus 93.4 426N2O 10024-97-2 0.004 lb/Million Btus 11.1 0.004 lb/Million Btus 11.4 0.004 lb/Million Btus 12.5 0.004 lb/Million Btus 13.3 0.004 lb/Million Btus 13.6 61.9CO2e 208.6 lb/Million Btus 656,278 208.6 lb/Million Btus 676,436 208.6 lb/Million Btus 739,900 208.6 lb/Million Btus 784,835 208.6 lb/Million Btus 803,529 3,660,978OtherH2SO4 7664-93-9 0.03 lb/Tons 4.1 0.03 lb/Tons 4.3 0.03 lb/Tons 5.9 0.06 lb/Tons 12.6 0.06 lb/Tons 12.9 39.7HF 7664-39-3 0.03 lb/Tons 4.2 0.03 lb/Tons 4.4 0.03 lb/Tons 6.1 0.06 lb/Tons 12.9 0.06 lb/Tons 13.2 40.7Pb 7439-92-1 4.2E-04 lb/Tons 0.1 4.2E-04 lb/Tons 0.1 4.2E-04 lb/Tons 0.1 4.2E-04 lb/Tons 0.1 4.2E-04 lb/Tons 0.1 0.4

Note: The PM, PM2.5 and PM10 emissions are based on relevant stack test data and applicable emission factors.

Projected Actual

Emissions(tpy)

Fuel Data

Projected Annual Emission Factor




Boiler 9Boiler 5 Boiler 6 Boiler 7 Boiler 8



Appendix 6

Appendix 6a - NSR Pollutant Emissions Increase for Project - Ancillary EquipmentAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

Units 1-4 Fly Ash Silo Bag Filter Vent 68.16 68.16 68.16 166.76 166.76 166.76 184.73 184.73 184.73 116.56 116.56 116.56 0.00 0.00 0.00

Units 7-9 TOXECON Powder Activated Carbon (PAC) Silo

Vent Filter75.55 75.55 75.55 565.65 565.65 565.65 98.70 98.70 98.70 23.15 23.15 23.15 466.95 466.95 466.95

Units 7-9 TOXECON Fly Ash Silo Bin Vent 55.27 55.27 55.27 413.78 413.78 413.78 72.20 72.20 72.20 16.93 16.93 16.93 341.59 341.59 341.59

Units 7-9 TOXECON Mechanical Exhauster Vents A and B 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Fly Ash Storage Silos Baghouse Filter Vent 353.98 353.98 353.98 391.37 391.37 391.37 433.53 433.53 433.53 79.55 79.55 79.55 0.00 0.00 0.00

Units 1-4 Fly Ash Building, Telescopic Loading Chute for Dry

Fly Ash303.09 143.35 21.71 303.36 143.48 21.73 820.03 387.85 58.73 516.95 244.50 37.02 0.00 0.00 0.00

Units 7-9 TOXECON Ash Unloading Building Chute (Wet) 10.17 4.81 0.73 173.35 81.99 12.42 12.47 5.90 0.89 2.30 1.09 0.16 160.88 76.09 11.52

Fly Ash Storage Silos Loading and Unloading Facility 305.26 144.38 21.86 408.14 193.04 29.23 456.45 215.89 32.69 151.20 71.51 10.83 0.00 0.00 0.00

Unit 1-4 Fly Ash 244.01 48.80 11.98 244.23 48.85 11.99 660.20 132.04 32.41 416.19 83.24 20.43 0.00 0.00 0.00

Unit 7-9 Fly Ash

(covered dump trucks and dry tanker trucks)613.97 122.79 30.14 830.94 166.19 40.79 929.30 185.86 45.62 315.33 63.07 15.48 0.00 0.00 0.00

DSI Silo Vent (New) 0.00 0.00 0.00 315.36 315.36 315.36 0.00 0.00 0.00 0.00 0.00 0.00 315.36 315.36 315.36Pebble Lime Silo Vent (New) 0.00 0.00 0.00 300.34 300.34 300.34 0.00 0.00 0.00 0.00 0.00 0.00 300.34 300.34 300.34

PAC Silo Vent (New) 0.00 0.00 0.00 75.09 75.09 75.09 0.00 0.00 0.00 0.00 0.00 0.00 75.09 75.09 75.09

Activated Carbon 1.70 0.34 0.08 6.45 1.29 0.32 1.70 0.34 0.08 0.00 0.00 0.00 4.75 0.95 0.23

PAC Delivery (New) 0.00 0.00 0.00 5.72 1.14 0.28 0.00 0.00 0.00 0.00 0.00 0.00 5.72 1.14 0.28

DSI Delivery (New) 0.00 0.00 0.00 108.12 21.62 5.31 0.00 0.00 0.00 0.00 0.00 0.00 108.12 21.62 5.31

Pebble Lime Delivery (New) 0.00 0.00 0.00 170.31 34.06 8.36 0.00 0.00 0.00 0.00 0.00 0.00 170.31 34.06 8.36

UNIT TOTAL5(LBS) 142.68 135.97 131.63 2,134.16 1,810.33 1,696.90 185.06 177.13 171.87 42.38 41.17 40.24 1,949.09 1,633.19 1,525.03

UNIT TOTAL5(TPY) 0.0713 0.0680 0.0658 1.067 0.905 0.848 0.09 0.09 0.09 0.021 0.021 0.0201 0.975 0.817 0.763

1. The baseline emissions are estimated assuming a baseline period starting 4/2008 and ending 3/2010 for PM, PM10 and PM2.5.

3. The capable of accomodating emissions are calculated based on the heat input and associated material handling throughputs the existing units could have accommodated during the baseline period unrelated to the project.4. The excludable emissions are calculated as the difference between the baseline emissions and the capable of accommodating emissions.5. The unit total includes all new units as well as any existing unit affected by the project that will see an increase in emissions as a result of the proposed project.

2. The future projected actual emissions for existing units are based on the projected heat input of the boilers and the associated material handling throughputs (coal, ash) corresponding to that rate. For new units the emissions are based on the potential emissions.

Projected Emissions Increase

Emission Unit Description

Baseline Period Emissions1 Future Emissions2 Capable of Accomodating3 Excludable Emissions4

Z:\2012\120697\WORK\Rept\PTI Application\NEW_April_WP_We_Emissions_2013_0304.xlsx Trinity Consultants

Appendix 6b - NSR Pollutant Baseline Emissions for Project - Ancillary EquipmentAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

PM

Emissions

(lbs)

PM10

Emissions

(lbs)

PM2.5

Emissions

(lbs)

EUASHHANDLING Units 1-4 Fly Ash Silo Bag Filter Vent 150.83 150.83 150.83 23.20 23.20 23.20 0.00 0.00 0.00 68.16 68.16 68.16

Units 7-9 TOXECON Powder Activated Carbon

(PAC) Silo Vent Filter80.59 80.59 80.59 80.59 80.59 80.59 40.29 40.29 40.29 75.55 75.55 75.55

Units 7-9 TOXECON Fly Ash Silo Bin Vent 58.95 58.95 58.95 58.95 58.95 58.95 29.48 29.48 29.48 55.27 55.27 55.27Units 7-9 TOXECON Mechanical Exhauster Vents

A and B0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00

Fly Ash Storage Silos Baghouse Filter Vent 353.98 353.98 353.98 353.98 353.98 353.98 353.98 353.98 353.98 353.98 353.98 353.98Units 1-4 Fly Ash Building, Telescopic Loading

Chute for Dry Fly Ash669.56 316.68 47.95 104.01 49.19 7.45 0.00 0.00 0.00 303.09 143.35 21.71

Units 7-9 TOXECON Ash Unloading Building

Chute (Wet)10.18 4.82 0.73 10.44 4.94 0.75 9.06 4.28 0.65 10.17 4.81 0.73

Fly Ash Storage Silos Loading and Unloading

Facility318.53 150.65 22.81 322.86 152.70 23.12 195.02 92.24 13.97 305.26 144.38 21.86

Unit 1-4 Fly Ash 539.06 107.81 26.46 83.74 16.75 4.11 - - - 244.01 48.80 11.98

Unit 7-9 Fly Ash

(covered dump trucks and dry tanker trucks)647.08 129.42 31.77 596.79 119.36 29.30 583.38 116.68 28.64 613.97 122.79 30.14

Activated Carbon 1.70 0.34 0.08 1.70 0.34 0.08 1.70 0.34 0.08 1.70 0.34 0.08

TOTAL (LBS) 2,830.44 1,354.06 774.15 1,636.25 860.00 581.53 1,212.89 637.28 467.08 2,031.15 1,017.43 639.46

TOTAL (TPY) 1.42 0.68 0.39 0.82 0.43 0.29 0.61 0.32 0.23 1.02 0.51 0.32

1. The baseline emissions are estimated assuming a baseline period starting 4/2008 and ending 3/2010 for PM, PM10 and PM2.5.

Baseline Period Emissions1

DescriptionEmission Unit

2008 2009 2010

Z:\2012\120697\WORK\Rept\PTI Application\NEW_April_WP_We_Emissions_2013_0304.xlsx Trinity Consultants

Appendix 7

of 3

Appendix 7 - Summary of USEPA RBLC DatabaseAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, MichiganRBLC ID Facility Type Fuel Permitting Year Averaging Period Control

0.50 LB/MMBTU 30 DAYS - - - - - -

0.50 LB/MMBTU 30 DAY ROLLING AVERAGE

- - - - - - 0.23 LB/MMBTU 30-DAY ROLLING AVG 0.15 LB/MMBTU 12-MONTH ROLLING AVG - - -

0.10 LB/MMBTU 30-DAY ROLLING 0.10 LB/MMBTU 12-MONTH ROLLING - - - 10.00 PPM -

- - -

- - -

0.15 LB/MMBTU EACH, 30D ROLL. AVG. EXCL. STRTUP&SHTDWN

27,446.40 LB/D EACH, 30D ROLLING AVG.

- - - 0.55 LB/MMBTU 30-DAY ROLLING AVG 34,449.00 T/YR - - - - 0.35 LB/MMBTU 30-DAY ROLLING AVG. - - - - - - 0.30 LB/MMBTU SEE NOTES 115.20 LB/H SEE NOTES - - -

0.12 LB/MMBTU 30-DAY ROLLING

0.12 LB/MMBTU 12-MONTH ROLLING - - -

8/9/2012

2/6/2012

1/12/2012

12/30/2010

12/28/2010

12/21/2010

12/17/2010

12/10/2010

6/25/2010

5/3/2010

4/28/2010

Capacity

*NE-0052 WHELAN ENGERGY CENTER UNIT 1 835 MMBTU/H SUBBITUMINOU

S COAL 8/10/2012

CO Emission Factor

GOOD COMBUSTION PRACTICES

*NE-0051 PLATTE GENERATING STATION COAL FIRED BOILER 1048 MMBTU/H SUBBITUMINOU

S COAL

*AZ-0055 NAVAJO GENERATING STATION

PULVERIZED COAL FIRED BOILER 7725 MMBTU/HR COAL

TX-0593 TEXAS CLEAN ENERGY PROJECT

Integrated Gasification Combined Cycle 400 MW PRB coal

*MI-0399 DETROIT EDISON--MONROE Boiler Units 1, 2, 3 and 4 7624 MMBTU/HR Coal

IA-0101 OTTUMWA GENERATING STATION Boiler #1 8669 MMBTU/H PRB Coal

TX-0585 TENASKA TRAILBLAZER ENERGY CENTER Coal-fired Boiler 8307 MMBTU/H Sub-bituminous

coal

MI-0391 TES FILER CITY STATION Coal fired boiler power plant 54 MW coal

TX-0554 COLETO CREEK UNIT 2 Coal-fired Boiler Unit 2 6670 MMBTU/H PRB coal

*MO-0084 NEW MADRID POWER PLANT UNIT 1 CYCLONE BOILER 7150 MMBTU/H COAL

OR-0047 BOARDMAN PLANT COAL-FIRED ELECTRIC GENERATING UNIT 350 T/H

SUB-BITUMINOUS COAL

MN-0081 BOSWELL ENERGY CENTER Boiler 4 600 MMBTU/H subbituminous

coal



Good combustion practices

good combustion controls

Good combustion practices.



Over-fired air

Good combustion practices

CO monitored by CEMS.

Z:\2012\120697\WORK\Rept\PTI Application\APP05_WP_We_RBLC_Boiler_2012_1203.xlsx 3/2/2013

of 3

Appendix 7 - Summary of USEPA RBLC DatabaseAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, MichiganRBLC ID Facility Type Fuel Permitting Year Averaging Period Control Capacity


S COAL 8/10/2012

CO Emission Factor


0.15 LB/MMBTU 30 D ROLL EXCEPT STARTUP/SHUTDOWN

28,826.00 LB/H 1-H FOR STARTUP/SHUTDOWN

0.15 LB/MMBTU 30 D ROLL EXCEPT STARTUP/SHUTDOWN

0.13 LB/MMBTU 24-HOUR ROLLING 1,023.80 LB/H 24-HOUR ROLLING - - -

779.00 LB/H AS A 3-HOUR AVERAGE EACH BOILER

3,410.00 T/YR PER ROLLING 12 MONTHS EACH BOILER

0.15 LB/MMBTU HEAT INPUT, AS A 3-HOUR ROLLING AVERAGE

0.25 LB/MMBTU 30-DAY ROLLING 1,175.00 LB/H 30-DAY ROLLING 5,146.50 T/YR -

0.25 LB/MMBTU 30-DAY ROLLING AVERAGE

463.00 LB/H 30-DAY ROLLING AVERAGE

- - - 0.25 LB/MMBTU 30 DAY ROLLING 600.00 LB/H 30 DAY ROLLING - - - 0.02 LB/MMBTU - - - - - - - 0.50 LB/MMBTU 30-DAY ROLLING AV - - - - - -

4/28/2010

12/29/2009

12/11/2009

10/8/2009

5/20/2009

5/20/2009

5/20/2009

TX-0598LIMESTONE ELECTRIC GENERATING STATION UNIT 3

PC Boiler 800 MW PRB coal

OH-0310AMERICAN MUNICIPAL POWER GENERATING STATION

BOILER (2), PULVERIZED COAL FIRED 5191 MMBTU/H PULVERIZED

COAL

MN-0081 BOSWELL ENERGY CENTER Boiler 4 600 MMBTU/H subbituminous

coal

MI-0389 KARN WEADOCK GENERATING COMPLEX BOILER 8190 MMBTU/H PRB COAL OR

50/50 BLEND

WY-0069 A NAUGHTON PLANT UNIT 2 2400 MMBTU/H COAL

WY-0069 B NAUGHTON PLANT UNIT 3 3700 MMBTU/H COAL 5/20/2009

WY-0068 WYODAK PLANT UNIT 1 4700 MMBTU/H COAL

WY-0069 NAUGHTON PLANT UNIT 1 1850 MMBTU/H COAL

NE-0049 OPPD NEBRASKA CITY STATION NCS UNIT 1 370 T/YR

POWDER RIVER BASIN COAL

2/26/2009

VA-0312 SPRUANCE GENCO, LLC ELECTRIC GENERATION 124392 T/YR COAL 1/23/2009

COMBUSTION CONTROLS


CO monitored by CEMS.

EFFICIENT COMBUSTION


GOOD COMBUSTION CONTROLS

COMBUSTION CONTROLS

COMBUSTION CONTROLS


of 3

Appendix 7 - Summary of USEPA RBLC DatabaseAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, MichiganRBLC ID Facility Type Fuel Permitting Year Averaging Period Control Capacity


S COAL 8/10/2012

CO Emission Factor


0.50 LB/MMBTU 30-DAY AVERAGE - - - - - - 0.50 LB/MMBTU 30 DAY AVERAGE - - - - - -

0.15 LB/MMBTU 30 DAY ROLLING AVERAGE

- - - - - - - - - - - - - - - 0.25 LB/MMBTU 30-DAY ROLLING 700.00 LB/H 30-DAY ROLLING - - - 0.20 LB/MMBTU 30-DAY ROLLING 820.00 LB/H 30-DAY ROLLING - - -

0.15 LB/MMBTU 30 DAYS ROLLING AVERAGE

- - -

- - -

0.18 LB/MMBTU 30-OPERATING DAY ROLLING

- - - - - -

0.15 MMBTU/H 30-OPERATING DAY ROLLING

- - - - - -

AZ-0050 CORONADO GENERATING STATION UNIT 2 4719 MMBTU COAL 1/22/2009

AZ-0050 A CORONADO GENERATING STATION UNIT 1 4719 MMBTU/H COAL 1/22/2009

WY-0065 DAVE JOHNSTON UNIT 3 1280319 T/YR COAL 6/27/2008

WY-0065 A DAVE JOHNSTON UNIT 4 1734370 T/YR COAL 6/27/2008

AR-0094 JOHN W. TURK JR. POWER PLANT PC BOILER 6000 MMBTU/H PRB SUB-BIT

COAL 11/5/2008

MI-0388 BELLE RIVER POWER PLANT

COAL-FIRED BOILER, UNIT #1 6209 MMBTU/H COAL 9/5/2008

FL-0306 AOUC CURTIS H. STANTON ENERGY CENTER

A 468 MEGAWATT (MW) FOSSIL FUEL FIRED STEAM ELECTRIC GENERATING UNIT (UNIT 2).

4286 MMBTU/H COAL 2/6/2008

OH-0314 SMART PAPERS HOLDINGS, LLC

PULVERIZED DRY BOTTOM BOILER 420 MMBTU/H COAL 1/31/2008

MO-0077 NORBORNE POWER PLANT MAIN BOILER 3762420 T/YR COAL 2/22/2008

FL-0306OUC CURTIS H. STANTON ENERGY CENTER

A 468 MEGAWATT (MW) FOSSIL FUEL FIRED STEAM ELECTRIC GENERATING UNIT (UNIT 1)

4286 MMBTU/H COAL 2/6/2008


COMBUSTION CONTROLS

GOOD COMBUSTION

EFFICIENT COMBUSTION

COMBUSTION CONTROLS

-


CEMS SHALL MONITOR AND

RECORD EMISSIONS

CEMS SHALL MONITOR AND

RECORD EMISSIONS


Appendix 8

of 1

Appendix 8a – BACT Economic Analyses for Combined EUSGUs 5 and 6 Input ParametersAir Use Permit to Install AQCS Retrofit PIPP Waste stream flow rate (scfm) 467,000We Energies, Marquette, Michigan Waste stream temperature (deg F) 180

Annual CO emission (tpy) 1183Gross heat of combustion (btu/lb, CO) 4,347Operating Labor Rate ($/hr) 30Maintenance Labor Rate ($/hr, OLR*1.1) 33Electricity Price ($/kwh) 0.03Natural Gas Price ($/mmBtu or $/mscf) 4Annual interest rate (fraction): 0.08Means CPI (1995 to 2012) 0.824404522Operating hours (hours/year) 8,760

AssumptionsOperating Temperature 1,400Destruction efficiency 80%

Capital Cost ComponentsEquipment Costs:-- Basic Equipment, e.g., Incinerator: $0.00-- Other (auxiliary equipment, etc.): $0.00Total Equipment Cost--base: $0.00Total Equipment Cost --escalated: $0.00Purchased Equipment Cost : $0.00Total Capital Investment (1995 $): $0.00Total Capital Investment (1998 $): $0.00

Annualized Cost ComponentsDirect Operating Costs:

Operating labor $16,425.00Supervisory labor $2,463.75Maintenance labor $18,067.50Maintenance materials $18,067.50Natural gas $29,030,350.95Electricity $148,789.16Catalyst replacement $0.00

Sub total $29,234,163.85Indirect Operating Costs:

Overhead $33,014.25Taxes, insurance, administrative $0.00Capital recovery $0.00

Total Annualized Cost($): $29,267,178.10Tons of CO Controlled (TPY): 946.4Cost Effectiveness: ($/ton Controlled) $30,924.74

1 Represents fuel costs only. No equipment capital costs included for thermal oxidation.

Thermal Oxidation 1Parameters

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Appendix 8b – BACT Economic Analyses for Each of EUSGU 7 Input ParametersAir Use Permit to Install AQCS Retrofit PIPP Waste stream flow rate (scfm) 255,556

Waste stream temperature (deg F) 179Annual CO emission (tpy) 648Gross heat of combustion (btu/lb, CO) 4,347Operating Labor Rate ($/hr) 30Maintenance Labor Rate ($/hr, OLR*1.1) 33Electricity Price ($/kwh) 0.03Natural Gas Price ($/mmBtu or $/mscf) 4Annual interest rate (fraction): 0.07Means CPI (1995 to 2012) 0.824404522Operating hours (hours/year) 8,760







Total Annualized Cost($): $16,067,329.28Tons of VOCs Controlled (TPY): 518.4Cost Effectiveness: ($/ton Controlled) $30,994.08


Thermal Oxidation 1Parameters


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Appendix 8c – BACT Economic Analyses for Each of EUSGUs 8 and 9 Input ParametersAir Use Permit to Install AQCS Retrofit PIPP Waste stream flow rate (scfm) 508,889We Energies, Marquette, Michigan Waste stream temperature (deg F) 335

Annual CO emission (tpy) 1,295Gross heat of combustion (btu/lb, CO) 4,347Operating Labor Rate ($/hr) 30Maintenance Labor Rate ($/hr, OLR*1.1) 33Electricity Price ($/kwh) 0.03Natural Gas Price ($/mmBtu or $/mscf) 4Annual interest rate (fraction): 0.07Means CPI (1995 to 2012) 0.824404522Operating hours (hours/year) 8,760







Total Annualized Cost($): $28,290,973.30Tons of VOCs Controlled (TPY): 1036Cost Effectiveness: ($/ton Controlled) $27,307.89


Thermal Oxidation 1

Z:\2012\120697\WORK\Rept\PTI Application\App8c CO PSD BACT Oxidation (8 & 9).xlsx 3/7/2013

HDR CO BACT-2013-02-06

Project Presque Isle Presque Isle Presque Isle

Unit 5&6 7 8&9

Title catalyst catalyst catalyst

INPUTS units Notes

boiler heat input Mbtu/hr 1,300 1,000 2,000

flue gas mass flow lb/hr 2,100,000 1,150,000 2,290,000 flow diagrams

flue gas temperature F 180 179 335 flow diagrams

flue gas O2 at fan discharge % 4.0 4.0 4.0 typical for PC boiler after airheater

equipment cost factors

thermal oxidizer $/scfm HDR file pricing from vendors

CO catalyst $/scfm 10 10 10 vendor budgetary pricing

CO catalyst housing and duct burner $/scfm 3 3 3 see catalyst box tab

ID booster fan $/scfm 3 3 3 $750,000 fan and motor for ~250,000 scfm for cat, $1M for RTO

ductwork $/scfm 0.5 0.5 0.5 10'x10'x100' long @ 25lb/ft2 @ $2500/ton for 250,000 scfm

foundations, erection, startup cost factor % of equipment 100% 100% 100%

engineering, indirects cost factor % of equipment 50% 50% 50%

annual maintenance cost factor % of catalyst + TO 33% 33% 33% 3 year warranty on catalyst, major overhaul of RTO every 5 yr

equipment thermal recovery efficiency % - uncorrected 0 0 0

equipment operating temperature F 550 550 550

equipment pressure drop in w.c. 5 5 5

equipment fan efficiency % 80 80 80

CO removal efficiency % 88 88 88

equipment minimum O2 required % 3 3 3

NG fuel cost $/Mbtu 4 4 4

electricity cost $/kWh 0.03 0.03 0.03

operating hours per year hr/year 7000 7000 7000

NG burner NOx emission factor lb/MBtu 0.11 0.11 0.11

operating lifespan years 20 20 20

future cost discount rate % per year 5% 5% 5%

CALCULATIONS units

flue gas volume flow scfm 466,667 255,556 508,889

dilution air required scfm 0 0 0

Equipment inlet flow scfm 466,667 255,556 508,889

CO inlet mass flow tpy 1,183 648 1,295

NOx inlet mass flow tpy 910 700 1,400

NOx added by NG burner tpy 71.8 39.4 45.5

equipment aux. burner load Btu/hr 186,480,000 102,396,000 118,164,000

equipment fan power HP 874 479 953

total equipment cost $ $7,700,000 $4,216,667 $8,396,667

foundations, erection, startup $ $7,700,000 $4,216,667 $8,396,667

engineering, indirects $ $3,850,000 $2,108,333 $4,198,333

total project capital cost $ $19,250,000 $10,541,667 $20,991,667

Capital Recovery Factor % 8.02% 8.02% 8.02%

annual fuel and electricity cost $/year 5,358,391$ 2,942,085$ 3,457,934$

Printed 2/8/2013, 10:19 AM Page 1 of 2

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Appendix 8d – BACT Economic Analysis for All EUSGUs (Catalyst) Air Use Permit to Install AQCS Retrofit PIPP We Energies, Marquette, Michigan

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HDR CO BACT-2013-02-06

Project Presque Isle Presque Isle Presque Isle

Unit 5&6 7 8&9

Title catalyst catalyst catalyst

annual maintenance cost $/year 1,540,000$ 843,333$ 1,679,333$

annual capital cost $/year 1,544,670$ 845,891$ 1,684,426$

total annual cost $/year 8,443,061$ 4,631,309$ 6,821,693$

CO cost to control $/ton 8,711$ 8,732$ 6,235$ Additional Nox emissions were included in the economic analysis.

Printed 2/8/2013, 10:19 AM Page 2 of 2

Appendix 9 Only the MDEQ’s copy of the Permit to Install

Application includes the CD containing the modeling input/output files.

Appendix 10

Appendix 10 - Building Parameter Modeling InputsAir Use Permit to Install AQCS Retrofit PIPP

Bldg ID Description Bldg Type

UTM NAD83X Coord.

(m)

UTM NAD83Y Coord.

(m)Elevation1, 4

(ft)Height2

(ft)Radius2,3

(ft)X Length2

(ft)Y Length2

(ft)U79PUMP Unit 7-9 Fly Ash Pumphouse RECT 469717.5 5158473.7 609.6 17.8 - 42.7 31.2U56PUMP Unit 5-6 Fly Ash Pumphouse RECT 469707.6 5158428.8 608.6 25.2 - 32.0 43.0BLD01 Fuels Building Hi Bay RECT 469535.9 5158619.1 614.1 39.0 - 79.4 45.3BLD02 Fuels Building Repair Area and Office Area RECT 469541.1 5158594.8 613.4 30.0 - 167.7 59.1BLD04 Fuels Building Low Bay RECT 469542 5158584.7 613.1 17.0 - 63.0 32.2BLD13T1 Units 7-9 Building RECT 469613.1 5158472 606.5 64.0 - 82.0 236.2BLD13T2 Units 7-9 Building RECT 469638 5158472 606.5 141.0 - 65.6 236.2BLD13T3 Units 7-9 Building RECT 469658 5158471.8 606.5 160.0 - 154.2 236.2BLD15T1 Units 1-4 Building RECT 469659.4 5158312.9 605.9 27.0 - 27.1 32.8BLD15T2 Units 1-4 Building RECT 469668.3 5158315.2 605.9 52.0 - 64.0 172.2BLD15T4 Units 1-4 Building RECT 469687.9 5158321.4 606.0 77.0 - 57.7 87.8BLD15T6 Units 1-4 Building RECT 469687.9 5158348 606.6 109.0 - 57.7 65.7BLD15T8 Units 1-4 Building RECT 469723.6 5158368.6 606.9 129.0 - 65.9 143.4BLD16 1-4 Baghouse RECT 469774.7 5158372.1 606.6 106.0 - 100.1 100.1BLD17 5&6 Baghouse RECT 469798.8 5158415.7 607.3 58.8 - 92.5 111.2BLD18 Sample Building RECT 469867.4 5158294.8 603.9 11.0 - 24.0 16.4BLD19 Guard Shack RECT 469753.8 5158294.4 604.6 12.0 - 21.0 18.4BLD21 Unit 2 CW Well House RECT 469651.9 5158280.5 605.3 10.3 - 28.2 20.0BLD22 Unit 1 CW Well House RECT 469666.5 5158280.5 605.2 10.3 - 28.2 20.0BLD23 Unit 3 CW Well House RECT 469637.4 5158280.5 605.3 10.3 - 28.2 20.0BLD24 Unit 4 CW Well House RECT 469620.8 5158281 605.3 10.3 - 28.2 20.0BLD26 Unit 5 CW Well House RECT 469602.6 5158301.1 605.8 12.4 - 33.5 32.8BLD27 Unit 6 CW Well House RECT 469584.3 5158301.1 605.8 12.4 - 33.5 32.8BLD32 1-6 Bottom Ash Pumphouse RECT 469566.4 5158353.3 606.8 13.8 - 84.6 41.0BLD35 Hydrogen Storage RECT 469595.6 5158422.7 608.8 11.5 - 57.4 18.7BLD36 ATC Building RECT 469569.2 5158447 609.4 12.5 - 23.6 48.2BLD37 Used Oil Building RECT 469596.1 5158467.7 610.0 20.0 - 56.4 26.9BLD38 Hazardous Waste Storage RECT 469487.8 5158541.2 611.7 16.0 - 51.8 40.4BLD39 Dry Storage RECT 469490.3 5158530.9 611.4 13.5 - 44.9 18.7BLD40 Fuel Oil Pump House RECT 469453.4 5158556.4 612.1 14.2 - 29.5 25.9BLD41 Rear Guard Shack RECT 468928.4 5158669.3 612.0 10.0 - 7.9 7.2BLD42 Unknown RECT 468928.5 5158666.8 612.0 10.0 - 15.4 7.5BLD43T1 Units 5 and 6 Building RECT 469613.3 5158422 606.5 64.0 - 86.9 162.4BLD43T2 Units 5 and 6 Building RECT 469639.7 5158421.8 606.5 127.0 - 59.1 162.4BLD43T3 Units 5 and 6 Building RECT 469657.8 5158421.8 606.5 133.0 - 81.4 162.4BLD43T4 Units 5 and 6 Building RECT 469682.7 5158421.7 606.5 88.0 - 77.1 162.4BLD47 Units 7-9 Wellhouse RECT 469526.5 5158311.3 602.2 14.1 - 92.8 41.0BLD57 7-9 Bottom Ash Pumphouse RECT 469723.3 5158558.5 612.1 13.8 - 60.7 36.1BLD48 Main SUF Building RECT 469991.7 5158551 607.0 69.5 - 37.7 53.1SUF SUF RECT 470234.2 5158434.2 602.1 50.0 - 34.0 34.0CRUSHER Coal Crusher House RECT 469757 5158378.5 606.9 50.5 - 30.0 35.0ELEC Coal Crusher Electrical RECT 469756.72 5158372.52 606.8 20.0 - 19.3 18.7TRANSFER Coal Transfer House RECT 469751.7 5158409.1 607.7 25.0 - 25.0 30.0BLD16L 1-4 Baghouse Lower RECT 469774.5 5158347.5 606.0 53.0 - 89.9 80.4BIHED00O Lime Treatment System RECT 469719.5 5158356.7 606.6 60.0 - 40.0 40.0BIHED00P Alternate Ash Recirculation System RECT 469719.3 5158344.6 606.3 15.0 - 40.0 40.0BIHED008 Mill Building RECT 469643.6 5158586.6 613.2 15.0 - 34.0 12.0BIHED00A Control Blower Building RECT 469656.2 5158602 613.6 15.0 - 46.0 24.0BLD28 1-6 Settling Tank CIRC 469558.8 5158341.3 606.4 39.0 26 - -BLD29 1-6 Surge Tank CIRC 469579.6 5158340.5 606.5 36.0 34 - -BLD30 1-6 Dewatering Bin A CIRC 469596.3 5158345.5 606.7 61.0 15 - -BLD31 1-6 Dewatering Bin B CIRC 469596.8 5158333.8 606.4 61.0 15 - -BLD44 Fly Ash Storage Facility (A) CIRC 468993.1 5158710.1 612.9 168.4 20.25 - -BLD45 Fly Ash Storage Facility (B) CIRC 469009.3 5158710.1 614.0 168.4 20.25 - -BLD51 7-9 Settling Tank CIRC 469728.8 5158583.1 613.0 24.0 30 - -BLD52 7-9 Surge Tank CIRC 469746.8 5158583.4 612.9 22.5 25 - -BLD53 Waste Holding Tank A CIRC 469728.4 5158548 611.7 32.0 20 - -BLD54 Waste Holding Tank B CIRC 469743.4 5158548.4 611.6 32.0 20 - -BLD55 7-9 Dewatering Bin CIRC 469711.3 5158587.6 613.2 67.0 17.62 - -BLD56 7-9 Dewatering Bin CIRC 469711.3 5158576.8 612.9 67.0 17.62 - -WTANK White Tank (Small fuel oil storage tank) CIRC 469464.7 5158570.9 612.7 30.0 6.56168 - -YTANK Yellow Tank (Large fuel oil storage tank) CIRC 469459.2 5158580.1 613.0 32.0 21.6378 - -


Z:\2012\120697\WORK\Rept\PTI Application\App10_WE-PIPP Building Modeling Inputs v1 0.xlsx Trinity Consultants

Appendix 10 - Building Parameter Modeling InputsAir Use Permit to Install AQCS Retrofit PIPP

Bldg ID Description Bldg Type

UTM NAD83X Coord.

(m)

UTM NAD83Y Coord.

(m)Elevation1, 4

(ft)Height2

(ft)Radius2,3

(ft)X Length2

(ft)Y Length2

(ft)


U79SILO Unit 7-9 Fly Ash Storage Silo CIRC 469724.5 5158467.5 609.4 102.5 16U56SILO Unit 5-6 Fly Ash Storage Silo CIRC 469725.2 5158423.7 608.3 87.0 14U14SILO Unit 1-4 Ash Silo CIRC 469789.1 5158356 606.1 85.0 14 - -PACSILO Unit 7-9 Powder Activated Carbon Silo CIRC 469688.4 5158557.4 612.3 46.0 10 - -BIHED00F New PAC Injection Silo CIRC 469721.9 5158494.5 610.0 50.0 7 - -BIHED00I DSI Trona Silo for Unit 7-9 CIRC 469643.6 5158589.4 613.3 60.0 7 - -BIHED00L Unit 7 SDA Stack CIRC 469753.1 5158503.3 609.9 112.9 15 - -BIHED00M Unit 6 SDA Stack CIRC 469756.8 5158482.6 609.4 112.9 15 - -BIHED00N Unit 5 SDA Stack CIRC 469760.3 5158462.1 608.9 112.9 15 - -BLD08 Office Building POLY 469603.8 5158572 612.8 52.8 - - -BLD10 Unit 7-9 Baghouse POLY 469647.4 5158587 613.2 81.5 - - -BLD15T3 Units 1-4 Building POLY 469669.1 5158413.4 608.3 72.0 - - -BLD15T5 Units 1-4 Building POLY 469705.6 5158368.1 607.0 107.0 - - -BLD15T7 Units 1-4 Building POLY 469711.1 5158413.4 608.1 123.0 - - -BLD33 Oil Storage Building POLY 469543.3 5158352.9 606.7 19.0 - - -

Z:\2012\120697\WORK\Rept\PTI Application\App10_WE-PIPP Building Modeling Inputs v1 0.xlsx Trinity Consultants

Appendix 11

Appendix 11a – Model Input Parameters - Truck Traffic CalculationsAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Paved Haul Road Equation

PM PM10 PM2.5 Basis

Paved haul road emission factor equation (2) from AP-42 13.2.1 (1/11) 0.011 0.0022 0.0005 AP-42, Section 13.2.1, Table 13.2.1-1, 11/06

Where: 150 150 150 Estimated from AP-42, Section 13.2.1, Figure 13.2.1-2, 11/06

E = Emission Factor (lb/VMT) 365 365 365

W = Average Weight (tons) of Vehicles on Road 1.05 1.05 1.05

AP-42, Section 13.2.1,Table 13.2.1-2, 01/11

Assumes silt loading for low volume roads (< 500 average daily

traffic vehicles). Silt loading calculated as a weighted average with

2.4 g/m2 used for Dec-Feb and 0.6 used for Mar-Nov.

# of Trucks

maximum

(trucks/day)1

Truck Weight

Empty3

(tons/truck)

Truck Weight Full3

(tons/truck)

PM Emission

Factor

(lb/VMT)

PM10 Emission

Factor

(lb/VMT)

PM2.5 Emission

Factor

(lb/VMT)

1 19.0 39.0 3.20E-01 6.40E-02 1.57E-02

5 19.0 39.0 3.20E-01 6.40E-02 1.57E-02

5 19.0 39.0 3.20E-01 6.40E-02 1.57E-02

Road Segment2

Distance of

Segment One Way2

(ft)

Distance of

Segment One Way

(mi)

New PAC Delivery DSI DeliveryPebble Lime

Delivery

A 2654.12 0.50 Y Y Y

B 489.283 0.09 Y Y

C 553.308 0.10 Y

PM Emissions

Road Segment2

Distance of

Segment Round

Trip

(ft)

Distance of

Segment Round

Trip

(mi)


Delivery

PM Emissions

(tons per day)

PM Emissions

(g/s)

A 5308.24 1.01 1.61E-04 8.04E-04 8.04E-04 1.77E-03 1.86E-02

B 978.566 0.19 2.97E-05 0.00E+00 1.48E-04 1.78E-04 1.87E-03

C 1106.616 0.21 0.00E+00 0.00E+00 1.68E-04 1.68E-04 1.76E-03

PM10 Emissions

Road Segment2

Distance of

Segment Round

Trip

(ft)

Distance of

Segment Round

Trip

(mi)


Delivery

PM10 Emissions

(tons per day)

PM10 Emissions

(g/s)

A 5308.24 1.01 3.22E-05 1.61E-04 1.61E-04 3.54E-04 3.72E-03

B 978.566 0.19 5.93E-06 0.00E+00 2.97E-05 3.56E-05 3.74E-04

C 1106.616 0.21 0.00E+00 0.00E+00 3.35E-05 3.35E-05 3.52E-04

PM2.5 Emissions

Road Segment2

Distance of

Segment Round

Trip

(ft)

Distance of

Segment Round

Trip

(mi)


Delivery

PM2.5 Emissions

(tons per day)

PM2.5 Emissions

(g/s)

A 5308.24 1.01 7.90E-06 3.95E-05 3.95E-05 8.69E-05 9.12E-04

B 978.566 0.19 1.46E-06 0.00E+00 7.28E-06 8.74E-06 9.17E-05

C 1106.616 0.21 0.00E+00 0.00E+00 8.23E-06 8.23E-06 8.64E-05

Notes:

TRUCK TRAFFIC

Particle Size Multiplier (k) (lb/VMT)

Number of Wet Days/yr (P)

Number of Days (N)

Silt loading (sL) (g/m2)

New PAC Delivery

DSI Delivery

Pebble Lime Delivery

1. Assume no more than 5 trucks will be unloading on any given day for Pebble Lime and DSI delivery and no more than one truck per day for new PAC delivery.

2. Vehicle delivery routes determined using image provided by Andrew Sutherland of HDR on December 7, 2012. Distances were determined using google earth on January 29, 2013.

3. Truck weights provided by We Energies PIPP Source Inventory dated 07-19-2010.

N

PWsLkVMTlbE

41)/(

02.191.0

Z:\2012\120697\WORK\Rept\PTI Application\PIPP_Rolling_Avg_2013_0301.xlsx Trinity Consultants

Appendix 11b – Model Input Parameters - Volume Source DeterminationAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Volume Source Parameter Calculations

Parameter inches meters Segment9

Segment Length9

(ft

traveled/Truck)

Segment

Length

(m)

Distance

between

Sources10

(m)

Number of

Sources11

(N)

PM Emissions

per segment

(g/s)

PM10

Emissions per

segment (g/s)

PM2.5

Emissions per

segment (g/s)

PM Emissions

per source

(g/s)

PM10

Emissions per

source (g/s)

PM2.5

Emissions

per source

(g/s)

Width of Truck1, 2

90 2.286 A 2654.12 808.98 12.95 63 1.86E-02 3.72E-03 9.12E-04 2.95E-04 5.90E-05 1.45E-05

Height of Truck2

138 3.505 B 489.283 149.13 12.95 12 1.87E-03 3.74E-04 9.17E-05 1.56E-04 3.11E-05 7.64E-06

Width of Road3

312 7.925 C 553.308 168.65 12.95 14 1.76E-03 3.52E-04 8.64E-05 1.26E-04 2.52E-05 6.17E-06

Adjusted Width of Road1, 4

- 13.925

Height of Volume Source1, 5

- 5.959

Initial Horizontal Dimension1, 6

- 6.477

Initial Vertical Dimension1,7

- 2.772

Release Height1,8

- 2.979

Notes:

4. The adjusted width is 6 m greater than the actual width of the road.

Emissions by Segment Emissions of Volume Sources by Segment

1. USEPA's Haul Road Guidance presented at the 10th Modeling Conference by Randy Robinson was used to generate volume source parameters. For parameters which Randy Robinson did not address, the Michigan Department of Environmental Quality

(MDEQ) guidance dated September, 2009 was used. For parameters where the MDEQ guidance is absent, Volume II of the User's Guide for the Industrial Source Complex (ISC3) Dispersion Models.

2. Average height of dump trucks assumed 11' 6'' to be the same as at Valley Power Plant and width estimated based on previous haul road modeling conducted by Trinity.

3. Width of road was measured from an aerial image of the the Presque Isle Power Plant using google earth.

11. N, the maximum number of sources that can be used to represent the road, is the length of the road divided by the distance between sources.

12. Imported terrain elevations via USGS Seamless Server NED files obtained February 3, 2011.

5. The height of the volume sources is 1.7 times the height of the truck.

6. The initial horizontal dimension for a road that is represented by adjacent volume sources is the adjusted width divided by 2.15.

7. The initial vertical dimension is the height of the volume source divided by 2.15.

8. The release height is half the height of the volume source.

9. Road segments determined using "We Energies Truck Traffic Map". Road segments were divided when necessary and the corresponding road legths were determined using google earth.

10. The distance between volume sources is two times the width of the volume source.

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Appendix 12

of 1

Year MonthBoiler 5 Op

HoursBoiler 6 Op

HoursBoiler 7 Op

HoursBoiler 8 Op

HoursBoiler 9 Op

Hours2008 4 704.02 720 0 720 7202008 5 481.77 735.01 545.98 668.19 397.542008 6 720 720 720 691.2 596.032008 7 640.7 642.7 744 726.95 7442008 8 744 744 744 712.93 699.182008 9 580.3 720 720 720 7202008 10 268.96 520.25 744 678.71 7442008 11 720 453.88 720 646.43 522.872008 12 744 744 583.93 713.27 02009 1 744 744 744 744 646.772009 2 672 672 672 631.94 6722009 3 614.87 744 721.4 0 7442009 4 720 720 154.72 636.64 7202009 5 717.94 696.95 568.63 726.49 634.012009 6 720 613.68 720 720 7202009 7 744 744 680.2 744 7442009 8 613.2 744 619.65 742.73 714.482009 9 98.72 720 628.68 719.6 640.322009 10 209.03 613.16 744 744 643.282009 11 408.8 142.75 720 720 573.482009 12 744 303.98 583.13 599.42 7442010 1 744 744 672.43 714.87 442.52010 2 591.14 672 672 308.53 610.832010 3 721.08 744 307.65 601.95 714.742010 4 654.63 573.01 238.9 720 7202010 5 440.72 681.05 604.26 744 631.432010 6 525.85 206.78 720 720 7202010 7 545.49 388.55 681.22 744 7442010 8 511.47 744 744 728.25 661.062010 9 66.57 627.09 673.69 673.38 7202010 10 650.42 181.2 669.97 734.87 7442010 11 720 561.87 720 687.73 208.82010 12 743.36 743.72 701.91 743.28 02011 1 735.31 592.11 622.07 604.45 641.42011 2 239.16 561.29 672 672 6722011 3 744 744 706.31 106.08 7442011 4 623.05 476.81 712.12 480.64 7202011 5 431.88 737.7 335.92 696.46 672.52011 6 599.05 453.71 711.31 720 652.932011 7 660.95 495.22 702.28 744 692.752011 8 380.67 743.45 711.83 744 743.272011 9 0 720 720 720 659.932011 10 0 650.98 643.76 744 718.662011 11 375.53 478.81 686.31 720 7202011 12 744 645.65 710.84 662.2 2392012 1 662.49 703.47 290.1 744 680.572012 2 638.25 696 696 124.3 6962012 3 744 744 80.05 744 714.422012 4 719.42 719.83 0 720 7202012 5 703.52 743.58 624.04 676.88 721.922012 6 720 465.19 91.04 633.22 636.782012 7 744 718.48 744 703.7 7442012 8 429.82 742.19 744 529.33 150.172012 9 642.9 428.75 588.65 523 399.472012 10 744 0 675.38 740.23 743.032012 11 359.7 407.88 720 720 7202012 12 0 670.55 744 629.46 744

Appendix 12a – Baseline Operating Hours


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Appendix 12b –Baseline Actual Hourly NOx Emissions

Year MonthBoiler 5 NOx

(lbs/hr)Boiler 6 NOx




(lbs/hr)

Combined Total NOx

(lbs/hr)2008 4 206.7 305.3 -- 381.8 391.6 1285.42008 5 248.8 278.6 326.6 336.0 341.6 1531.52008 6 283.2 284.8 328.5 354.9 355.7 1607.02008 7 290.0 296.0 360.1 382.3 389.7 1718.22008 8 302.2 317.4 340.1 362.9 363.5 1686.12008 9 261.2 291.8 361.2 384.9 387.4 1686.52008 10 271.1 295.2 351.2 377.0 380.0 1674.42008 11 278.5 254.4 313.3 325.0 330.0 1501.22008 12 272.7 296.8 316.6 342.0 -- 1228.12009 1 288.3 296.2 329.3 343.4 346.1 1603.42009 2 233.1 236.7 329.0 343.8 347.6 1490.22009 3 203.6 208.0 333.0 -- 352.2 1096.92009 4 211.2 212.9 275.2 319.1 315.0 1333.52009 5 249.4 256.6 273.8 294.3 293.3 1367.52009 6 295.9 277.3 310.6 336.1 331.0 1550.82009 7 266.7 292.4 319.9 352.6 347.1 1578.82009 8 278.1 318.1 312.0 333.1 329.3 1570.62009 9 189.8 311.2 323.7 344.7 329.0 1498.32009 10 151.3 300.6 341.2 369.5 362.7 1525.32009 11 253.4 212.2 321.4 344.8 339.9 1471.72009 12 282.0 276.9 306.3 328.7 331.4 1525.32010 1 275.2 311.2 320.1 338.0 323.4 1567.92010 2 270.2 288.6 344.3 347.0 368.8 1618.82010 3 213.5 220.1 320.4 339.6 341.4 1435.12010 4 190.3 195.8 283.8 329.8 326.4 1326.12010 5 188.7 220.0 319.5 349.2 351.1 1428.52010 6 223.5 252.8 324.4 353.2 358.7 1512.52010 7 244.2 221.0 330.3 364.9 359.3 1519.72010 8 233.0 238.5 320.7 352.3 343.5 1488.12010 9 214.1 245.0 347.1 374.3 372.3 1552.72010 10 301.2 299.2 348.5 376.0 366.0 1691.02010 11 321.8 295.4 351.3 370.5 356.7 1695.72010 12 316.8 317.4 350.6 372.7 -- 1357.52011 1 242.8 250.2 313.8 329.8 321.7 1458.22011 2 192.7 218.2 337.8 353.4 349.8 1451.92011 3 222.4 239.3 324.1 300.7 344.2 1430.72011 4 196.9 200.8 309.9 313.5 322.0 1343.22011 5 235.6 251.7 326.4 326.8 321.3 1461.82011 6 217.9 244.3 319.2 338.3 332.7 1452.42011 7 256.6 237.4 319.6 342.9 337.2 1493.72011 8 215.3 228.3 294.4 313.3 310.8 1362.12011 9 -- 210.8 289.5 304.3 294.0 1098.62011 10 -- 211.1 276.9 293.7 287.7 1069.42011 11 166.8 211.7 273.6 286.9 284.1 1223.02011 12 157.9 174.1 267.1 269.1 267.2 1135.42012 1 154.7 161.2 233.2 253.6 250.9 1053.52012 2 167.1 165.4 251.0 199.5 260.8 1043.72012 3 156.5 174.3 181.3 222.7 224.9 959.82012 4 144.5 171.0 -- 223.5 227.0 765.92012 5 149.9 181.2 216.0 227.5 233.0 1007.72012 6 141.2 190.7 241.1 215.5 218.3 1006.82012 7 147.6 177.1 269.1 281.9 282.8 1158.42012 8 134.7 131.2 230.3 224.7 237.8 958.72012 9 138.2 144.7 233.0 228.8 234.3 978.92012 10 152.7 -- 264.8 268.3 271.4 957.22012 11 147.1 136.6 263.6 266.8 273.3 1087.42012 12 -- 129.3 244.8 244.1 255.4 873.6



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Appendix 12c –Baseline Actual SO2 Emissions

Year MonthBoiler 5 SO2

(lbs/hr)Boiler 6 SO2




(lbs/hr)

Combined Total SO2

(lbs/hr)2008 4 495.6 682.5 -- 461.1 469.0 2108.22008 5 527.0 611.8 400.9 407.0 415.7 2362.52008 6 556.3 590.2 416.0 445.4 449.2 2457.12008 7 592.8 628.0 458.4 484.0 489.1 2652.32008 8 626.4 643.1 407.3 436.4 435.7 2548.92008 9 583.9 599.1 418.8 449.4 456.8 2507.92008 10 576.8 713.0 431.3 455.2 469.0 2645.32008 11 613.4 586.4 402.1 410.3 421.9 2434.12008 12 614.4 627.1 428.0 457.9 -- 2127.52009 1 657.9 666.7 435.4 451.6 461.0 2672.62009 2 570.3 568.7 431.6 450.9 455.8 2477.42009 3 525.1 543.0 438.7 -- 465.9 1972.72009 4 526.6 517.9 373.4 437.3 431.2 2286.42009 5 568.0 575.3 375.3 396.9 394.2 2309.62009 6 584.5 584.3 413.2 445.3 438.7 2466.02009 7 575.2 621.5 422.9 451.7 451.2 2522.42009 8 579.5 636.6 375.2 404.0 400.2 2395.42009 9 497.9 651.6 408.8 442.7 418.7 2419.52009 10 339.5 605.2 427.9 468.9 461.2 2302.62009 11 507.8 457.3 399.0 431.5 414.8 2210.52009 12 561.7 565.0 369.0 401.9 395.3 2293.02010 1 555.8 606.1 389.4 407.5 388.0 2346.82010 2 575.3 607.7 421.5 431.2 452.1 2487.82010 3 500.0 502.9 395.3 415.1 420.7 2234.02010 4 440.6 451.6 361.2 420.6 414.8 2088.82010 5 422.6 457.2 378.5 420.1 409.0 2087.42010 6 470.2 508.4 391.3 425.8 425.4 2221.12010 7 537.2 466.6 401.2 438.3 433.6 2277.02010 8 509.9 519.3 373.1 402.5 395.7 2200.62010 9 453.3 501.4 422.9 451.6 449.9 2279.02010 10 580.2 602.6 432.8 466.4 454.2 2536.22010 11 763.0 763.5 415.2 433.1 432.6 2807.32010 12 844.4 859.0 413.1 434.0 -- 2550.62011 1 495.6 644.5 377.0 395.5 391.3 2303.92011 2 341.7 388.6 412.9 428.8 424.8 1996.82011 3 546.8 566.4 392.7 364.7 412.0 2282.72011 4 540.6 557.8 371.9 383.8 387.8 2241.82011 5 637.8 608.8 426.6 435.1 432.4 2540.62011 6 455.5 553.4 368.4 393.9 385.3 2156.52011 7 690.4 678.2 390.2 421.5 413.5 2593.82011 8 546.9 607.8 353.8 382.1 376.8 2267.42011 9 -- 485.4 380.0 406.8 391.0 1663.32011 10 -- 520.4 398.7 433.9 420.1 1773.12011 11 267.7 405.5 400.9 432.6 422.9 1929.62011 12 300.0 295.0 389.2 409.7 364.4 1758.32012 1 297.9 300.1 374.2 408.4 394.3 1774.92012 2 295.6 286.8 384.2 315.3 411.3 1693.22012 3 255.9 291.8 264.1 360.4 354.8 1526.92012 4 222.6 270.6 -- 344.9 335.3 1173.52012 5 270.7 320.6 348.8 372.5 380.7 1693.22012 6 243.5 289.0 357.4 332.3 332.9 1555.22012 7 254.1 292.5 396.7 423.4 421.6 1788.32012 8 238.6 255.8 376.3 374.8 393.0 1638.52012 9 274.9 285.5 376.5 368.6 379.5 1685.02012 10 291.4 -- 406.2 416.9 411.5 1526.02012 11 287.8 298.4 404.5 422.0 423.3 1836.02012 12 -- 290.4 379.9 392.7 399.2 1462.3

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Appendix 12d –Baseline Actual CO Emissions

Year MonthBoiler 5 CO

(lbs/hr)Boiler 6 CO

(lbs/hr)Boiler 7 CO

(lbs/hr)Boiler 8 CO

(lbs/hr)Boiler 9 CO

(lbs/hr)

Combined Total CO (lbs/hr)

2008 4 75.09 119.08 -- 10.17 8.76 213.102008 5 82.27 113.17 10.43 9.12 7.76 222.752008 6 87.52 110.67 10.28 9.38 7.81 225.662008 7 89.21 112.70 11.06 10.10 8.58 231.652008 8 95.18 116.46 10.58 9.64 8.15 240.012008 9 87.14 107.17 11.02 10.20 8.47 224.012008 10 84.73 114.67 11.05 10.08 8.65 229.182008 11 89.10 100.99 10.25 8.97 7.64 216.962008 12 90.43 112.60 10.55 9.63 -- 223.212009 1 92.38 111.71 10.82 9.77 8.38 233.062009 2 79.29 94.23 10.62 9.70 8.17 202.012009 3 69.28 86.39 10.66 -- 8.12 174.452009 4 74.98 89.60 8.99 9.01 7.49 190.062009 5 82.36 102.34 9.12 8.32 7.04 209.182009 6 89.58 106.54 10.25 9.41 7.96 223.752009 7 85.03 111.99 10.54 9.86 8.31 225.732009 8 87.45 115.53 10.08 9.20 7.70 229.972009 9 75.14 116.84 10.70 9.87 7.94 220.492009 10 52.78 108.42 10.86 10.05 8.15 190.262009 11 77.36 81.24 10.34 9.52 7.85 186.312009 12 85.09 103.26 9.94 9.14 7.70 215.142010 1 85.39 109.64 10.28 9.27 7.54 222.112010 2 84.31 106.22 11.04 9.58 8.41 219.562010 3 73.66 87.54 10.18 9.22 7.73 188.332010 4 68.42 81.52 8.96 8.95 7.43 175.292010 5 70.66 88.95 10.19 9.38 7.82 187.012010 6 76.58 95.74 10.38 9.51 8.04 200.252010 7 80.45 84.20 10.31 9.72 8.11 192.792010 8 77.65 92.05 9.98 9.34 7.83 196.862010 9 73.75 97.20 10.84 9.84 8.30 199.932010 10 92.00 113.96 10.87 10.08 8.32 235.232010 11 97.47 111.18 10.84 9.91 7.96 237.362010 12 95.26 117.25 10.68 9.90 -- 233.082011 1 84.63 99.52 9.61 8.89 7.38 210.032011 2 75.99 94.35 10.51 9.65 8.06 198.562011 3 75.95 95.09 10.07 8.17 7.85 197.132011 4 76.57 91.94 9.76 8.70 7.43 194.422011 5 80.44 97.90 10.25 8.82 7.36 204.762011 6 78.28 96.35 10.18 9.16 7.63 201.612011 7 80.56 94.89 10.31 9.36 7.74 202.862011 8 75.99 93.35 9.35 8.61 7.20 194.502011 9 -- 93.71 9.51 8.68 7.10 119.002011 10 -- 91.21 9.99 9.26 7.60 118.062011 11 66.02 90.66 10.21 9.46 7.78 184.122011 12 69.96 80.44 9.77 8.78 7.44 176.392012 1 68.52 81.11 8.86 8.47 7.02 173.982012 2 70.33 81.46 9.42 6.58 7.25 175.042012 3 61.76 83.15 6.61 7.68 6.46 165.662012 4 56.82 81.93 -- 7.85 6.57 153.172012 5 60.91 82.63 8.28 7.56 6.59 165.972012 6 58.16 79.07 8.92 7.10 6.05 159.312012 7 60.37 80.14 10.00 9.18 7.69 167.382012 8 56.16 69.31 9.26 7.90 6.84 149.482012 9 61.97 77.44 8.74 7.44 6.46 162.052012 10 67.58 -- 9.85 8.95 7.40 93.782012 11 66.09 75.76 9.97 9.10 7.55 168.48

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Appendix 12e –Baseline Actual PM2.5 Emissions

Year MonthBoiler 5 PM2.5

(lbs/hr)Boiler 6 PM2.5




(lbs/hr)2008 4 13.383 16.778 -- 16.230 15.9292008 5 14.268 15.313 13.085 14.179 15.8122008 6 14.446 14.677 15.826 14.158 12.9112008 7 14.958 15.273 15.410 14.791 15.9872008 8 16.592 16.522 15.331 13.722 14.4972008 9 15.338 15.307 15.072 15.372 15.8832008 10 14.763 15.783 15.764 14.685 16.2202008 11 16.668 14.709 13.732 12.324 15.2852008 12 17.189 17.390 14.344 14.008 --2009 1 18.641 19.616 15.203 14.246 15.1672009 2 16.024 16.611 14.907 13.773 15.3462009 3 13.800 14.198 13.781 -- 15.1772009 4 14.368 14.213 9.637 12.794 14.9902009 5 15.889 16.057 12.792 11.602 13.1392009 6 16.904 16.415 14.794 13.873 14.1332009 7 16.363 17.287 15.491 14.375 14.7972009 8 16.823 18.026 13.578 13.872 14.3432009 9 14.305 18.058 14.544 14.327 13.6802009 10 10.241 17.960 15.858 15.362 13.8872009 11 15.308 13.941 14.601 14.242 13.5032009 12 17.207 16.669 13.173 13.119 14.7692010 1 17.428 18.132 13.980 14.069 13.8322010 2 17.064 17.666 15.868 13.791 14.9182010 3 14.896 14.740 14.875 13.274 14.9062010 4 13.058 13.704 7.273 14.418 14.9842010 5 12.330 13.268 13.712 14.947 13.7182010 6 13.165 14.462 13.671 14.902 14.7272010 7 13.937 12.319 13.487 14.970 15.0902010 8 13.376 13.885 14.596 13.918 14.3002010 9 12.745 14.549 14.819 15.011 15.6782010 10 16.166 16.881 14.777 15.617 15.7862010 11 16.623 15.282 15.164 14.594 14.8142010 12 16.306 16.038 14.423 14.707 --2011 1 8.823 8.544 14.237 12.423 13.8592011 2 8.062 8.034 15.173 13.902 15.1022011 3 12.917 13.032 13.941 12.267 13.7702011 4 13.601 12.667 13.118 11.563 15.4892011 5 14.118 13.964 14.019 13.375 14.1192011 6 14.498 13.340 14.323 13.283 14.6532011 7 12.952 14.021 15.267 13.806 16.2712011 8 10.257 14.185 12.901 13.219 12.8822011 9 -- 12.110 13.369 13.387 12.3312011 10 -- 12.199 12.881 14.449 13.9252011 11 7.465 7.929 13.308 14.240 14.6752011 12 8.085 7.789 13.730 12.581 13.7932012 1 7.816 7.675 10.001 13.545 12.6882012 2 8.030 7.718 13.114 3.523 13.5282012 3 7.213 7.967 8.310 12.462 11.0522012 4 6.461 7.601 -- 11.883 11.8152012 5 6.981 7.880 10.033 12.265 11.9892012 6 6.925 7.624 9.271 11.430 10.9562012 7 7.143 7.609 13.782 13.659 13.8512012 8 6.610 6.573 12.707 11.730 10.4942012 9 7.350 7.322 12.044 11.703 11.0272012 10 8.045 -- 13.142 13.683 13.5252012 11 7.836 7.139 13.185 13.888 13.4902012 12 -- -- -- -- --



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Appendix 12f – Baseline Actual PM10 Emissions

Year MonthBoiler 5 PM10

(lbs/hr)Boiler 6 PM10




(lbs/hr)2008 4 13.383 16.778 -- 16.230 15.9292008 5 14.268 15.313 13.085 14.179 15.8122008 6 14.446 14.677 15.826 14.158 12.9112008 7 14.958 15.273 15.410 14.791 15.9872008 8 16.592 16.522 15.331 13.722 14.4972008 9 15.338 15.307 15.072 15.372 15.8832008 10 14.763 15.783 15.764 14.685 16.2202008 11 16.668 14.709 13.732 12.325 15.2852008 12 17.189 17.390 14.344 14.008 --2009 1 18.641 19.616 15.203 14.246 15.1672009 2 16.024 16.611 14.907 13.773 15.3462009 3 13.800 14.198 13.781 -- 15.1772009 4 14.368 14.213 9.637 12.794 14.9902009 5 15.889 16.057 12.792 11.602 13.1392009 6 16.904 16.415 14.794 13.873 14.1332009 7 16.363 17.287 15.491 14.375 14.7972009 8 16.823 18.026 13.578 13.872 14.3432009 9 14.305 18.058 14.544 14.327 13.6802009 10 10.241 17.960 15.858 15.362 13.8872009 11 15.309 13.941 14.601 14.242 13.5032009 12 17.207 16.669 13.173 13.119 14.7692010 1 17.428 18.132 13.980 14.069 13.8322010 2 17.064 17.666 15.868 13.791 14.9182010 3 14.896 14.740 14.875 13.274 14.9062010 4 13.058 13.704 7.273 14.418 14.9842010 5 12.330 13.268 13.712 14.947 13.7182010 6 13.165 14.462 13.671 14.902 14.7272010 7 13.937 12.319 13.487 14.970 15.0902010 8 13.377 13.885 14.596 13.918 14.3002010 9 12.745 14.549 14.819 15.011 15.6782010 10 16.166 16.881 14.777 15.617 15.7862010 11 16.623 15.282 15.164 14.594 14.8142010 12 16.306 16.038 14.423 14.707 --2011 1 8.823 8.544 14.237 12.423 13.8592011 2 8.062 8.034 15.173 13.902 15.1022011 3 12.917 13.032 13.941 12.267 13.7702011 4 13.601 12.667 13.118 11.563 15.4892011 5 14.118 13.964 14.019 13.375 14.1192011 6 14.498 13.340 14.323 13.283 14.6532011 7 12.952 14.021 15.267 13.806 16.2712011 8 10.257 14.185 12.901 13.219 12.8822011 9 -- 12.110 13.369 13.387 12.3312011 10 -- 12.199 12.881 14.449 13.9252011 11 7.465 7.929 13.308 14.240 14.6752011 12 8.085 7.789 13.730 12.581 13.7932012 1 7.816 7.675 10.001 13.545 12.6882012 2 8.030 7.718 13.114 3.523 13.5282012 3 7.213 7.967 8.310 12.462 11.0522012 4 6.461 7.601 -- 11.883 11.8152012 5 6.981 7.880 10.033 12.265 11.9892012 6 6.925 7.624 9.272 11.430 10.9562012 7 7.143 7.609 13.782 13.659 13.8512012 8 6.610 6.573 12.707 11.730 10.4942012 9 7.350 7.322 12.044 11.703 11.0272012 10 8.045 -- 13.142 13.683 13.5252012 11 7.836 7.139 13.185 13.888 13.4902012 12 -- -- -- -- --



Appendix 13

469,735 5,158,450

Local Local Source

PERMIT UTM UTM X Coord Y Coord Dist. Hgt. Dia Temp Flow Velocity Discharge SOURCE

SRN COMPANY ADDRESS CITY ZIP COUNTY NO. POL (pph) (tpy) TYPE ZONE EAST NORTH (meters) (meters) (km) (ft) (inches) (deg F) (ACFM) (m/s) Type DESCRIPTION

M3792 NORTHERN MICHIGAN UNIVERSITY 1401 PRESQUE ISLE AVENUE MARQUETTE 49855 MARQUETTE 126-05 NO2 22.8 100.0 NAAQS 16 468,868 5,156,624 -867 -1,826 2.0 150.0 60.0 300.0 47,000 12.2 Vertical 2 NEW BOILERS, DECOMISSION 2 OLD BOILERS

M3792 NORTHERN MICHIGAN UNIVERSITY 1401 PRESQUE ISLE AVENUE MARQUETTE 49855 MARQUETTE 29-11 NO2 14.9 65.3 NAAQS 16 468,833 5,156,640 -902 -1,810 2.0 85.0 42.0 302.0 29,500 15.6 Vertical 1 MW BIOMASS STOKER BOILER

FACILITY UTM:

Facility Stack Information

Emissions

Appendix 14

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Appendix 14 – Model Input Parameters - Existing PIPP NOx Emission SourcesAir Use Permit to Install AQCS Retrofit PIPPWe Energies, Marquette, Michigan

Easting NorthingFire Pump FIREPUMP 469595 5158303 605.8071 9 0.5 600 0.001 230 0.031 0.41Generators 1-6 GEN1_6 469703 5158325 605.9055 87 1.5 860 0.001 250 335.25 0.031 0.59Generators 1-7 GEN7_9 469707 5158516 606.4961 33 0.875 600 0.001 400 536.4 0.031 0.95

Maximum Annual Operating Hours

= 500

Power output in hp calculated based on conversion factor of 1 kW = 1.341 hp.NOX Emission Factors from AP-42, Section 3.3, Gasoline and Diesel Industrial Engines, Table 3.3-1 (10/96) for Diesel Fuel Emission Factors.

Stack Diameter

(feet)Source Model Name


Base Elevation

(feet)

Stack Height (feet)

Annual Average NOx Emission Rate

(lb/hr)

Exhaust Temperature

(deg F)

Exit Velocity

(m/s)Capacity

(kW)Capacity

(HP)

NOx Emission

Rate (lb/HP-hr)

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Air PTI Application - Department of Environmental · PDF file3/8/2013 . PTI Application Form...

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