### MICHIGAN DEPARTMENT OF ENVIRONMENTAL QUALITY
AIR QUALITY DIVISION

January 11, 2012

PERMIT TO INSTALL

63-08C

ISSUED TO Marathon Petroleum Company LP

LOCATED AT

1300 South Fort Street Detroit, Michigan

IN THE COUNTY OF Wayne

STATE REGISTRATION NUMBER

A9831

The Air Quality Division has approved this Permit to Install, pursuant to the delegation of authority from the Michigan Department of Environmental Quality. This permit is hereby issued in accordance with and subject to Section 5505(1) of Article II, Chapter I, Part 55, Air Pollution Control, of the Natural Resources and Environmental Protection Act, 1994 PA 451, as amended. Pursuant to Air Pollution Control Rule 336.1201(1), this permit constitutes the permittee’s authority to install the identified emission unit(s) in accordance with all administrative rules of the Department and the attached conditions. Operation of the emission unit(s) identified in this Permit to Install is allowed pursuant to Rule 336.1201(6).

DATE OF RECEIPT OF ALL INFORMATION REQUIRED BY RULE 203: 

## October 26, 2011

DATE PERMIT TO INSTALL APPROVED: 

## January 11, 2012 SIGNATURE:

DATE PERMIT VOIDED: SIGNATURE:

DATE PERMIT REVOKED: SIGNATURE:Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 1 of 103

PERMIT TO INSTALL

Table of Contents

Section Page

Alphabetical Listing of Common Abbreviations / Acronyms ........................................................................ ........... 2

General Co nditions ............................................................................................................. .................................... 3

Special Co nditions ............................................................................................................. ..................................... 5

Emission Unit I dentification................................................................................................... .................................. 5

Flexible Group Identification.................................................................................................. ................................ 12

Emission Unit Spec ial Conditions ............................................................................................... .......................... 14
EG11-FCCU...................................................................................................................... ................................ 14
EG27-ZURN BOILER................................................................................................................ ......................... 19
EU27-B&WBO ILER1................................................................................................................ ......................... 22
EG42-43SUL RECOV................................................................................................................ ........................ 25
EG70-COKER ..................................................................................................................... .............................. 30
EG-COKERFLARE .................................................................................................................. ......................... 34
EG72-SULR BLOCK2................................................................................................................ ........................ 37

Flexible Group S pecial Condi tions.............................................................................................. .......................... 41
FG-HEATERS ..................................................................................................................... .............................. 41
FGFLARES ....................................................................................................................... ................................ 53
FG-PROC VENTS................................................................................................................... ........................... 61
FGGROUP2 ....................................................................................................................... ............................... 62
FG-IFRTA NKS .................................................................................................................... .............................. 64
FG-EFRTANKS.................................................................................................................... ............................. 70
FG29-IGF ....................................................................................................................... ................................... 76
FG-PROC UNITS................................................................................................................... ............................ 78
FG-CRUDETANKS .................................................................................................................. ......................... 82
FG-NAPHTHATANKS................................................................................................................ ....................... 83
FG-COOLT OWERS.................................................................................................................. ........................ 86 FG-FirePumps................................................................................................................... ................................ 90
FGDHOUPA NNUAL.................................................................................................................. ........................ 92

Table B-1:Source-W ide Require ments ............................................................................................. .................... 95

Appendice s ..................................................................................................................... ...................................... 99 Appendix A: Continuous Emission Monitoring System Requirements for NO X , SO 2 , O 2 , and CO................... 99 Appendix B: Recordkeeping Provisions – Actual to Projected-Actual Applicabilit y Test................................ 100Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 2 of 103

Common Abbreviations / Acronyms

Common Acronyms Pollutant/Measurement Abbreviations

AQD Air Quality Division BTU British Thermal Unit
ANSI American National Standards Institute °C Degrees Celsius
BACT Best Available Control Technology CO Carbon Monoxide

CAA Clean Air Act dscf Dry standard cubic foot
CEM Continuous Emission Monitoring dscm Dry standard cubic meter
CFR Code of Federal Regulations °F Degrees Fahrenheit
COM Continuous Opacity Monitoring gr Grains

EPA Environmental Protection Agency Hg Mercury

EU Emission Unit hr Hour

FG Flexible Group H 2 S Hydrogen Sulfide
GACS Gallon of Applied Coating Solids hp Horsepower

GC General Condition lb Pound

HAP Hazardous Air Pollutant m Meter

HVLP High Volume Low Pr essure * mg Milligram

ID Identification mm Millimeter

LAER Lowest Achievable Emission Rate MM Million
MACT Maximum Achievable Control Technology MW Megawatts
MAERS Michigan Air Emissions Reporting System ng Nanogram

MAP Malfunction Abatement Plan NO

x Oxides of Nitrogen

MDEQ Michigan Department of Environmental Quality PM Particulate Matter

MIOSHA Michigan Occupational Safety & Health

Administration PM10 PM less than 10 microns diameter

MSDS Material Safety Data Sheet PM2. 5 PM less than 2.5 microns diameter

NESHAP National Emission Standard for Hazardous

Air Pollutants pph Pound per hour

NSPS New Source Performance Standards ppm Parts per million

NSR New Source Review ppmv Pa rts per million by volume

PS Performance Specification ppmw Parts per million by weight
PSD Prevention of Significant Deteriorati on psia Pounds per square inch absolute

PTE Permanent Total Enclosure psig Pounds per square inch gauge

PTI Permit to Install scf Standard cubic feet
RACT Reasonably Available Control Technology sec Seconds
ROP Renewable Operating Permit SO 2 Sulfur Dioxide

SC Special Condition THC Total Hydrocarbons

SCR Selective Catalytic Reduction tpy Tons per year
SRN State Registration Number μg Microgram
TAC Toxic Air Contaminant VOC Volatile Organic Compounds

TEQ Toxicity Equivalence Quotient yr Year

VE Visible Emissions

* For High Volume Low Pressure (HVLP) applicators, t he pressure measured at the HVLP gun air cap shall not exceed ten (10) pounds per square inch gauge (psig).Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 3 of 103

GENERAL CONDITIONS

1. The process or process equipment covered by this permit shall not be reconstructed, relocated, or modified, unless a Permit to Install authorizing such action is issued by the Department, except to the extent such action is exempt from the Permit to Install requirements by any applicable rule. (R 336.1201(1))

2. If the installation, construction, reconstruction, relo cation, or modification of the equipment for which this permit has been approved has not commenced within 18 months, or has been interrupted for 18 months, this permit shall become void unless otherwise authori zed by the Department. Furthermore, the permittee or the designated authorized agent sh all notify the Department via the Supervisor, Permit Section, Air Quality Division, Michigan Department of Envir onmental Quality, P.O. Box 30260, Lansing, Michigan 48909, if it is decided not to pursue the installation, co nstruction, reconstruction, relocation, or modification of the equipment allowed by this Permit to Install. (R 336.1201(4))

3. If this Permit to Install is issued for a process or process equipment located at a stationary source that is not subject to the Renewable Operating Permit prog ram requirements pursuant to R 336.1210, operation of the process or pr ocess equipment is allowed by this permit if the equipment performs in accordance

with the terms and conditions of this Permit to Install. (R 336.1201(6)(b))

4. The Department may, after notice and opportunity for a hearing, revoke this Permit to Install if evidence indicates the process or process equipment is not pe rforming in accordance with the terms and conditions of this permit or is violating the De partment’s rules or the Clean Air Act. (R 336.1201(8), Section 5510 of Act 451, PA 1994)

5. The terms and conditions of this Permit to Insta ll shall apply to any person or legal entity that now or hereafter owns or operates the process or process equipm ent at the location authorized by this Permit to Install. If the new owner or operat or submits a written request to the Department pursuant to R 336.1219 and the Department approves the request, this permit 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 R 336.1219 and shall be sent to the District Supervisor, Air Quality Division, Michigan Department of Environmental Quality. (R 336.1219)

6. Operation of this equipment shall not result in th e emission of an air contaminant which causes injurious effects to human health or safety, animal life, plant life of significant economic value, or property, or which

causes unreasonable interference with the comfortable enjoyment of life and property. (R 336.1901)

7. The permittee shall provide notice of an abnormal co ndition, start-up, shutdown, or malfunction that results in emissions of a hazardous or toxic air pollu tant which continue for more than one hour in excess of any applicable standard or limitati on, or emissions of any air contaminant continuing for more than two hours in excess of an applicable standar d or limitation, as required in Rule 912, to the Department. The notice shall be provided not later than two business days after start-up, shutdown, or discovery of the abnormal condition or malfunction. Written reports, if r equired, must be filed with the Department within 10 days after the start-up or shutdown occurred, within 10 days after the abnormal conditions or malfunction has been corrected, or wi thin 30 days of discovery of the abnormal condition or malfunction, whichever is first. The written reports shall inclu de all of the information required in Rule 912(5). (R 336.1912)

8. Approval of this permit does not exempt the permittee from complying with any future applicable requirements which may be promulgated under Part 55 of 1994 PA 451, as amended or the Federal
Clean Air Act.

9. Approval of this permit does not obviate the necess ity of obtaining such permits or approvals from other units of government as required by law.

10. Operation of this equipment may be subject to ot her requirements of Part 55 of 1994 PA 451, as amended and the rules promulgated thereunder.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 4 of 103

11. Except as provided in subrules (2) and (3) or unless the special conditions of the Permit to Install include an alternate opacity limit established pursuant to s ubrule (4) of R 336.1301, t he permittee shall not cause or permit to be discharged into the outer air from a process or process equipment a visible emission of density greater than the most stringent of the foll owing. The grading of visible emissions shall be

determined in accordance with R 336.1303. (R 336.1301)

a) A six-minute average of 20 perce nt opacity, except for one six-minut e average per hour of not more than 27 percent opacity. b) A visible emission limit specified by an app licable federal new source performance standard. c) A visible emission limit specified as a condition of this Permit to Install.

12. Collected air contaminants shall be removed as ne cessary 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 out er air. Transport of collected air contaminants in Priority I and II areas requires the use of material handling methods specified in R 336.1370(2). (R 336.1370)

13. The Department may require the permittee to conduct acceptable performance tests, at the permittee’s expense, in accordance with R 336.2001 and R 336. 2003, under any of the conditions listed in

R 336.2001. (R 336.2001)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 5 of 103



### SPECIAL CONDITIONS

Emission Unit Identification

Emission Unit ID Emission Unit Description * Stack Identification

EG05-CRUDE Crude Unit. Area 5. The crude unit separates crude oil into various fractions through the use of distillation processes.

These fractions are sent to other units in the refinery for further processing. The crude unit consists of process vessels (including heat exchangers and fractionation columns), the Alcorn heater, tanks, containers, compressors, pumps, piping, drains and various components (pump and compressors seals, process valves, pressure relief valves, flanges, connectors, etc.). Other EG’s have been created to address individual pieces of equipment within the crude unit which have specific applicable requirements. Permit:

262-02 None

EG05-CRUDEHTR Crude Alcorn Heater, Area 5, Fuel: Refinery fuel gas, and Natural gas, Permit: 108-02,
262-02, 175-06 SV04-H1-05-H1

EG04-VACUUM Vacuum Unit. Area 4. The vacuum unit separates the reduced crude from the crude unit through the use of a vacuum column. The reduced crude is separated into light vacuum gas oil, medium vacuum gas oil, heavy vacuum gas oil, and a bottoms product

called flux. The various fractions are sent to other units in the refinery for further processing. The vacuum unit consists of process vessels (including heat exchangers and vacuum column), two process heaters, tanks, containers, 2 cooling towers, flare, compressors, pumps, piping drains, and various components (pumps and compressor seals, process valves, pressure relief valves, flanges, connectors, etc.). Other EG’s have been created to address individual pieces of equipment within the vacuum unit that have specific applicable requirements. Permit

262-02 None

EG04-VACHTR Vacuum Heater. Area 4. Fuel: Refinery fuel gas and natural gas. Permit: 108-02, 262-02,

175-06 SV04-H1-05-H1

EG04-VAC2HTR Vacuum Heater. Area 4. Fuel: Refinery fuel gas and natural gas. SV04-H2Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 6 of 103



### Emission Unit ID Emission Unit Description * Stack Identification EG08-GOHT Gasoil Hydrotreater Unit: Area 8. Reacts sour gasoil streams with hydrogen over a catalyst bed to remove sulfur. The GOHT unit consists of process vessels (reactors, distillation tower, absorbing towers, stripper tower) and a charge heater, cooling tower, flare, compressors, pumps, piping, drains, & various components (pumps & compressor seals, process valves, pressure relief valves, flanges, connectors, etc.). Other EG’s were created to address individual pieces of equipment within this unit that have specific applicable requirements

. Permit: 262-02. None

EG08-GOHTCHARHTR Gasoil Hydrotreater Charge Heater. Area 8. Fuel: Refinery fuel gas and natural gas.

Permit: 262-02. SV08-H1

EG09-ALKDIBREBHTR Alkylation deisobutanizer heater. Area 9: Fuel: refinery fuel gas and natural gas. SV09-H7

EG09-ALKYLATION Alkylation Unit: Area 9: The Alkylation unit reacts isobutane with olefins in the presence of sulfuric acid to produce alkylate, a high octane gasoline blending component. Reaction products are sent for further processing and separation in the fractionating

section. Products from the unit include offgas, alkylate, butane, isobutane, and propane. Off-gas is routed to the refinery fuel gas system. Alkylate, butane, and propane are directed to storage. Isobutane is recycled through the system for further processing. Alkylation unit consists of process vessels (including fractionators, reactor and caustic scrubber), heaters, tanks, containers, cooling tower, flare, compressors, pumps, piping, drains, and various components (pump and compressor seals, process valves, pressure relief valves, flanges, connectors, etc.) Other

EG’s were created to address individual pieces of equipment within the Alkylation Unit which have specific applicable requirements.

Permit 262-02. NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 7 of 103



### Emission Unit ID Emission Unit Description * Stack Identification EG11-FCCU Fluid Catalytic Cracking Unit. Area 11. The FCCU converts heavier hydrocarbons to lighter products in the presence of a catalyst. In the process coke is deposited on the catalyst. The spent catalyst is moved to the regenerator (11-V1) where the coke is burned off using air. The regenerator is equipped with cyclones to capture catalyst (11- V1CYCLONES). The hot flue gas from the regenerator is directed to a flue gas cooler

where heat is recovered as steam. The FCCU consists of proc ess vessels (reactors, regenerator, fractionators, knock-out pots, and strippers) heater, tanks, containers, 2 cooling towers, compressors, pumps, piping, drains, and various components (pumps, and compressor seals, process valves, pressure relief valves, flanges, connectors, etc.).

Other EGs have been created to address equipment that has specific applicable requirements. Permit 262-02, 28-02A, 175-

06. SVFCCU

EG12-GASCON Gas Concentration Unit. Area 12. The Gas Con Unit processes liquids and off-gases

from the FCCU main column overhead and various other hydrocarbons (liquid and gas) and produces gasoline and liquid petroleum gas. The Gas Con Unit consists of process vessels (including reboilers, condensers, exchangers, absorbers, and distillation columns) tanks, containers, compressors, pumps, piping, drains, and various components, (pump and compressor seals, process valves, pressure relief valves, flanges, connectors, etc.). Other EG’s have been created to address individual pieces of equipment with the Gas Concentration Unit that have specific applicable requirements.

Permit 262-02. NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 8 of 103



### Emission Unit ID Emission Unit Description * Stack Identification EG16-NAPHHYTREAT Naphtha Hydrotreater Unit – Area 16. The NHT unit uses hydrogen to remove sulfur and nitrogen from straight-run and coker naphthas. The process uses a catalyst to promote the desulfurization reaction. The desulfurized or sweet naphtha is blended into gasoline or used for platformer feed. The NHT unit consists of process vessels (including exchangers, reactors, receivers, separators, and a stripper column.) heaters, tanks, containers, pumps, piping, drains, and various components, (pump seals, process valves, pressure relief valves, flanges, connectors, etc. Other EG’s have been created to address individual pieces of equipment which have specific applicable requirements. Permit 262-02. None

EG16-NHTSTRIPREBOIL Naphtha Hydr otreater Stripper Reboiler. Area 16. Fuel: Refinery fuel gas, and natural gas. Permits: C-11495, 108-02, 262-02 SV16-H3

EG16-NHTCHARHTR Naphtha Hydrotreater Charge Heater. Area 16. Fuel: refinery fuel gas and natural gas. Permit: C-11493, 108-02, 262-02 SV16-H4

EG19-KEROHYTREAT Kerosene Hydrotreater Unit. Area 19. The KHT unit uses hydrogen to remove sulfur and nitrogen from kerosene (and occasionally Naphtha). The process, called hydrotreating, uses a catalyst with hydrogen and temperature to promote the desulfurization reactor. The KHT unit consists of process vessels (including exchangers, a reactor, a receiver, separators, and a stripper column), a heater, tanks, containers, pumps, compressors, piping, drains, and various components (pump, and compressors, seals, process valves, pressure relief valves, flanges, connectors, etc.). Another EG have been created to address the charge heater, which has specific applicable requirements.

Permit 262-02. None

EG19-KHTCHARHTR Kerosene Hydrotreater Charge Heater. Area 19. Fuel: Refinery fuel gas, and natural gas. Permits C-11494, 108-02, 262-02 SV19-H2

EG22-TANKFARMS Tank Farm, Area 22. This emission group

covers the three tanks farm areas. Permit

262-02 None

EG27-ZURNBOLER Gas-fired boiler, Area 27. Fuel: Refinery fuel gas and natural gas. Permit C-9022. SV27-BR7

EU27-B&WBOILER1 Gas-fired boiler, Area 27. Fuel: Refinery fuel gas and natural gas. Permit 67-02. SV-B&WBOILER1Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 9 of 103



### Emission Unit ID Emission Unit Description * Stack Identification EG70-COKER Delayed Coker. Area 70. The Coker converts Vacuum Resid (Crude Vacuum Tower Bottoms), a product normally sold as asphalt or blended into residual fuel oil, into lighter, more valuable products. The Vacuum

Resid feedstock is heated before it enters the main fractionator, where lighter material vaporizes. The fractionator bottoms are routed through a fired heater and then into a

coke drum. This emission unit consists of process vessels (fractionators), coke drums, heater, cooling tower, compressors, pumps, piping, drains, & various components (pumps & compressor seals, process valves, pressure relief valves, flanges, connectors, etc.). This emission group includes the Coke Handling System, which will collect, size, and transport the petroleum coke created during the coking process. This system consists of a coke pit, storage pad, enclosed crusher, enclosed conveyors, and surge bins. Other

EG’s were created to address individual pieces of equipment within this unit that have specific applicable requirements. SV70-V1

EG70-COKERHTR Coker Charge Heater. Area 70. Fuel: Refinery fuel gas and natural gas. SV70-H1

EG71-H2HTR Hydrogen Plant Heater. Area 71. Fuel: Refinery fuel gas, pressure swing absorption gas, Syngas, and natural gas. SV71-H1

EG71-H2PLANT Hydrogen Plant. Area 71. The H2 Plant will process natural gas, refinery fuel gas and/or a high-pentane refinery stream to produce 99.9% pure hydrogen and high-pressure steam through the use of a steam/methane reforming technology. This emission unit consists of process vessels, heater, compressors, pumps, piping, drains, & various components (pumps & compressor seals, process valves, pressure relief valves, flanges, connectors, etc.). Other EG’s were created to address individual pieces of equipment within this unit that have specific applicable requirements. NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 10 of 103



### Emission Unit ID Emission Unit Description * Stack Identification EG71-H2STEAMSYS Hydrogen Plant Deaerator, Blowdown Vent, and Steam Vent. Area 71. During normal operation, small quantities of VOC may be emitted from the Hydrogen Plant Deaerator and the Blowdown Vent. During periods of startup, shutdown, and unanticipated outages, small quantities of VOC may be emitted from the Hydrogen Plant Deaerator, Blowdown Vent, and Steam Vent.. SV71-DEAERATOR

SV71-BLOWDOWN

SV71-PRODSTEAM

EG-COKERFLARE Coker Plant Flare. Area 76. SV76-FS EG77-DHTHYTREAT Distillate Hydrotreater Unit: Area 77. Reacts sour distillate (and occasionally gas oil) streams with hydrogen over a catalyst bed to

remove sulfur. The DHT unit consists of process vessels (reactors, distillation tower, absorbing towers, stripper tower), heater, cooling tower, compressors, pumps, piping, drains, & various components (pumps & compressor seals, process valves, pressure relief valves, flanges, connectors, etc.).

Other EG’s were created to address individual pieces of equipment within this unit that have specific applicable requirements. None

EG77-DHTHTR Distillate Hydrotreater Heater. Area 77. Fuel: Refinery fuel gas and natural gas. SV77-H1

EG72-SULRBLOCK2 Sulfur Block 2. Area 72. The Sulfur Block removes hydrogen sulfide from acid gas and converts it to elemental sulfur using Claus Process (Trains D and E), the SCOT Tail Gas Treating Unit process (Trains No. 3 and No. 4), and associated amine treating equipment. The exhaust tail gas is routed to a thermal oxidizer. This emission group consists of process vessels (including thermal reactors, an absorbing tower, and a stripping tower), heaters, tanks, containers, compressors, seals, process valves, flanges, connectors, etc.). Other EG’s have been

created to address individual units which have specific applicable requirements. SV72-V22

EG73-SOURWATER2 Sour Water Stripper. Area 73. The Sour Water Stripper removes hydrogen sulfide (H2S) and ammonia from the sour water stream in distillation towers heated by steam. The acid gases from the tower are routed to the Sulfur Plant. The stripped sour water is sent to the refinery sewer system. This emission group includes all equipment (pumps, tanks, vessels) in this area. NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 11 of 103



### Emission Unit ID Emission Unit Description * Stack Identification EGTANK104 Tank 104, an internal floating roof tank for the storage of petroleum liquids with a true V.P. of 11 psia or less. Capacity 4,673,000 gallons. None

EGTANK120 Tank 120, an internal floating roof tank for the storage of petroleum liquids with a true V.P. of 11 psia or less. Capacity 4,744,000 gallons. None

EGTANK601 Tank 601, an external floating roof tank for the storage of wastewater. Capacity = 4,200,000 gallons. None

EGTANK216 Tank 216, an internal floating roof tank for the storage of sour water from EG72- SULRBLOCK2. Capacity = 1,500,000 gallons. None

EG24P1 Diesel-driven fire water booster pump SV-24P1 EG24P2 Diesel-driven fire water booster pump SV-24P2 EGCOOLTOWERA Cooling tower A None EGCOOLTOWERC Cooling tower C None EGCOOLTOWERD Cooling tower D None EGCOOLTOWERE Cooling tower E None EGCOOLTOWERF Cooling tower F None EGCOOLTOWERG Cooling tower G None EGCOOLTOWERH Cooling tower H None EGCOOLTOWERNEW New cooling tower installed as part of the heavy oil upgrade project. None

EG76-UTILITIES Coker plant flare and flare gas recovery systems. Area 76. None

EG78-FUELGASRECOVERY Fuel gas recovery compressor. Area 78. None Changes to the equipment described in this table are subject to the requirements of R 336.1201, except as allowed by R 336.1278 to R 336.1290. * Emission units and emission groups that appear in th is permit that are not listed in the emission unit identification tables in this permit are describ ed in the renewable operating permit for the facility



### .

These conditions include the following two existing Emission Groups for completeness. Some equipment covered by this Permit to Install (PTI) belongs in these groups, but was not modified by the Detroit HOUP, nor were their conditions changed in this PTI.

Emission Unit ID Emission Unit Description Stack Identification EG-NSPSQQQ All individual drain systems, oil-water separators and the aggregate facilities that are subject to 40 CFR 60, Subpart QQQ. A current list of subject items is maintained by the refinery. None

EG-BENZNESHAP All equipment at the facility subject to the requirements of the Benzene Waste NESHAP NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 12 of 103



### Flexible Group Identification

Flexible Group ID Emission Units Included in Flexible Group Stack

Identification FG-HEATERS EG04-VACHTR, EG 04-VAC2HTR, EG05-CRUDEHTR, EG08-GOHTCHARHTR, EG09-ALKDIBREBHTR, EG11-FCCUCHARHTR, EG14-CCRPLCHARHTR, EG14-CCRPLINTHTR, EG16-NHTSTRIPREBOIL, EG16-NHTCHARHTR, EG19-KHTCHARHTR, EG22-FUELOILHTR, EG27-ZURNBOILER, EG27-B&WBOILER1, EG70-COKERHTR, EG71-H2HTR,

EG77-DHTHTR None

FG-CRUDE/VACHTRS EG04-VACHTR, EG05-CRUDEHTR None FGFLARES EG-CRUDEFLARE, EG -UNIFFLARE, EG-ALKYFLARE, EG-CPFLARE, EG-COKERFLARE None

FG-PROCVENTS EG06-VENTV34, EG09-VENTV5, EG11-VENT14SUMP, EG11-VENT21XF, EG11-VENT14XH, EG11-VENT21V47, EG21-S2OFFGAS None

FG-PROCUNITS EG04-VACUUM, EG05-CRUDE, EG08-GOHT, EG09-ALKYLATION, EG 11-FCCU, EG12-GASCON, EG13-PROPYLENE, EG14-CCRPLATFORMER, EG16-NAPHHYTREAT, EG19-KEROHYTREAT, EG21-CPTREATER, EG22-TANKFARMS, EG22-LPGRAILRACK, EG22-ASPHLOAD, EG29-WASTEWATER, EG38-ROUGETERMNL, EG42-43SULRECOV, EG99-LPGLOADRACK, EG41-SOURWATER, EG70-COKERPLANT, EG71-H2PLANT, EG72-SULRBLOCK2, EG73-SOURWATER2, EG77-DHTHYTREAT, EG76-UTILITIES, EG78-FUELGASRECOVERY None

FG-EFRTANKS EGTANK32, EGTANK 33, EGTANK108, EGTANK109, EGTANK110, EGTANK112, EGTANK113, EGTANK114, EGTANK115, EGTANK128, EGTANK129, EGTANK130, EGTANK601, EG29TANK40, EG29TANK41 None

FG29TANKS40-41 EG29TANK40, EG29TANK41 None FG-GROUP2 EGTANK2, EGTANK 9, EGTANK11, EGTANK16, EGTANK17, EGTANK18, EGTANK24, EGTANK27, EGTANK28, EGTANK30, EGTANK31, EGTANK42, EGTANK43, EGTANK50, EGTANK52, EGTANK54, EGTANK56, EGTANK59, EGTANK60, EGTANK62, EGTANK63, EGTANK64, EGTANK66, EGTANK70, EGTANK71, EGTANK100, EGTANK102, EGTANK103, EGTANK104, EGTANK105, EGTANK106, EGTANK107, EGTANK120, EGTANK125, EGTANK126, EGTANK127, EGTANK128, EGTANK314, EGTANK315, EGTANK316, EGTANK317, EGTANK318, EGTANK319, EGTANK320, EGTANK324, EGTANK603, EGTANK608 None

FG29-IGF EG29-IGF1, EG29-IGF2 None FG-TANKS133&134 EGTANK133, EGTANK134 None FG-CRUDETANKS EGTANK112, EG TANK113, EGTANK114, EGTANK115, EGTANK129, EGTANK130 NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 13 of 103



### Flexible Group ID Emission Units Included in Flexible Group Stack

Identification FGNAPHTHATANKS EGTANK19, EGTA NK40, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK49, EGTANK53, EGTANK55, EGTANK57, EGTANK58, EGTANK61, EGTANK72, EGTANK79, EGTANK101, EGTANK104, EGTANK108, EGTANK109, EGTANK110, EGTANK116, EGTANK120, EGTANK128, EGTANK135 None

FG-IFRTANKS EGTANK6, EGTA NK8, EGTANK19, EGTANK23, EGTANK40, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK49, EGTANK51, EGTANK53, EGTANK55, EGTANK57, EGTANK58, EGTANK61, EGTANK72, EGTANK79, EGTANK101, EGTANK104, EGTANK116, EGTANK120, EGTANK135, EGTANK507, EGTANK508, EGTANK216 None

FGCOOLTOWERS EGCOOLTOWERA, EGCOOLTOWERC, EGCOOLTOWERD, EGCOOLTOWERE, EGCOOLTOWERF, EGCOOLTOWERG, EGCOOLTOWERH, and EGCOOLTOWERNEW None

FGFirePumps EG24P1, EG24P2 None FGDHOUPANNUAL EG11-FCCU, EG14- CCRPLCATREG, EG21-S2OFFGAS, FG29-IGF, EG42-SULRECOV, EG70-COKER, EG-COKERFLARE, EG72-SULRBLOCK2, FG-HEATERS, FG-PROCUNITS, FGCOOLTOWERS, FGFIREPUMPS, FGHOUPTANKS, EG71-H2STEAMSYS None

FGREFINEFLARES EG-CRUDEFLARE, EG-UNIFFLARE, EG-ALKYFLARE,

EG-CPFLARE None

FGHOUPTANKS EGTANK16, EGTA NK17, EGTANK19, EGTANK23, EGTANK24, EGTANK27, EGTANK28, EGTANK40, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK49, EGTANK50, EGTANK53, EGTANK54, EGTANK55, EGTANK56, EGTANK57, EGTANK58, EGTANK59, EGTANK60, EGTANK61, EGTANK62, EGTANK63, EGTANK64, EGTANK70, EGTANK71, EGTANK72, EGTANK100, EGTANK101, EGTANK102, EGTANK103, EGTANK104, EGTANK105, EGTANK106, EGTANK107, EGTANK108, EGTANK109, EGTANK110, EGTANK112, EGTANK113, EGTANK114, EGTANK115, EGTANK116, EGTANK120, EGTANK125, EGTANK126, EGTANK127, EGTANK128, EGTANK129, EGTANK130, EGTANK507, EGTANK508, EGTANK601, EGTANK216, EG29TANK40, EG29TANK41 NoneMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 14 of 103



### Emission Unit Special Conditions

TABLE E-1.3 {EG11-FCCU}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

EMISSION GROUP Fluid Catalytic Cracking Unit. Area 11. The FCCU converts heavier hydrocarbons to lighter products in th e presence of a catalyst. In the process coke is deposited on the catalyst. The spent catalyst is moved to the regenerator (11-V1) where the coke is burned off using air. The regenerator is equipped with cyclones to capture catalyst (11-V1CYCLONES). The hot flue gas from the regenerator is directed to a flue gas cooler where heat is recovered as steam. The FCCU consists of process vessels (reactor, regenerator, fractionators, knock-out pots, and strippers) heater, tanks, containers, 2 cooling towers, compressors, pumps, piping, drains, and various components (pumps, and compressor seals, process valves, pressure relief valves , flanges, connectors, etc.). Other EGs have been created to address equip ment that has specific applicable requirements. Permit 262-02, 28-02A, 175-06, 379-08. Flexible Grouping ID FG-PROCUNITS, FGDHOUPANNUAL

I. DESIGN PARAMETERS

A. Pollution Control Equipment Cyclone, Electrostatic precipitat or (ESP) with ammonia addition.

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d. Air

Flow

Rate (acfm) Applicable Requirement

1. SVFCCU 195 60 R 336.1225, R 336.1226(d), R 336.2804, 40 CFR 52.21(d) C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS
A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutant Maximum Emission Limit

1. Particulate Matter 1. Permittee shall not ca use or allow the emission of particulate matter from any fluid catalytic cracking unit catalyst regenerator in excess of 0.8 pound per 1,000 pounds of coke burn off in the regenerator. (40 CFR 60.102(a)(1), 40 CFR 63.1564)

2. Carbon Monoxide 1. Permittee shall limit CO emissions, excluding periods of startup, shutdown, and malfunction, to 500 ppmv, dry basis, based on a 1-hour block average. (R 336.2810(3)), (R 336.280 4), (40 CFR 52.21(d)), (40 CFR 60.103), (40 CFR 63.1565)

3. Sulfur Dioxide 1. Permittee shall not cause or allow the emission of sulfur dioxide from the FCCU regenerator in excess of the following:

a. 70 ppmv (at 0% oxygen)-7 day rolling average‡ b. 35 ppmv (at 0% oxygen)-365 day rolling average (R 336.2802), (40 CFR 52.21), (55 FR 11029, Consent Order No. 01-40119) ‡ Note that if Marathon is operating in accordance with an approved Hydrotreater Outage Plan, the 7 day average limit does not apply during periods of hydrotreat er outages nor to startup, shutdown, and malfunction events approved in the Hydrotreater Outage Plan.

4. NOx 1. Permittee shall not cause or allow the emission of NOx from the FCCUMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 15 of 103



### TABLE E-1.3 {EG11-FCCU}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS
regenerator in excess of the following:

a. 123 ppmv (at 0% oxygen)-7 day rolling average‡ b. 93 ppmv (at 0% oxygen)-365 day rolling average (R 336.1801), (40 CFR 52.21), (55 FR 11029), (Consent Order No. 01-40119)

‡ Note that if Marathon is operati ng in accordance with an approved Hydrotreater Outage Plan, the 7 day average limit does not apply during periods of hydrotreat er outages nor to startup, shutdown, and malfunction events approved in the Hydrotreater Outage Plan. 5. Volatile Organic Compounds 1. Permittee shall lim it VOC emissions to 21 tons per year, based on a rolling 12-month time period as determined at the end of each calendar

month. (R 336.1702(a)) 6. PM-10 (particulate matter of 10 microns diameter or less) 1. Permittee shall not cause or allow the emission of PM-10 from the fluid catalytic cracking unit catalyst regenerator in excess of 1.1 pounds per 1,000 pounds of coke burn off in the regenerator. (R 336.1205), (R 336.2802), (40 CFR 52.21)

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. Opacity (R 336.1213(3)), (40 CFR Part 60 Subpart J)

2. NOx (R 336.1213(3)) 3. CO concentration by volume (R 336.1213(3))

4. SO2 (R 336.1213(3)) 5. Oxygen (R 336.1213(3)) 6. The permittee shall install, certify, calibrate, maintain, and operate the CEMS in accordance with the requ irements of 40 CFR §§60.11, 60.13, and Part 60, Appendix A, the applicable performance specification test of 40 CFR Part 60 Appendices B and F. With respect to 40 CFR Part 60 Appendix F, in lieu of the requirements of 40 CFR Part 60 Appendix F §§5.1.1, 5.1.3, and 5.1.4, the permittee shall conduct either a Relative Accuracy Audit (RAA) or a Relative Accuracy Test Audit (RATA) once every twelve calendar quarters, provided that a Cylinder Gas Audit is conducted each calendar quarter. Within 30 days following the end of each calendar qua rter, the permittee shall submit the results to the AQD in the format of the data assessment report. (R 336.1213(3)) 2. Process Monitoring System and Recordkeeping 1. Daily records of average coke burn-off rate, in 1,000 pounds per hour, and of hours of operation. (40 CFR Part 60 Subparts A & J), (40 CFR Part 63 Subparts A & UUU) 3. Other Monitoring and/or Recordkeeping 1. Process weight rate. (R 336.1213(3)), (R 336.1331(1)(e)) 2. Daily records of NOx em issions from the CEM. (R 336.1205), (R 336.2802), (40 CFR 52.21), (55 FR 11029), (Consent Order No. 01-40119) 3. Daily records of SO2 emissions from the CEM. (40 CFR Part 60 Subparts A & J, 40 CFR Part 63 Subparts A and UUU) 4. Daily records of CO em issions from the CEM. (40 CFR Part 60 Subparts A & J, 40 CFR Part 63 Subparts A and UUU) 5. The permittee shall calculate the VOC emission rates from EG11- FCCU monthly, for the preceding 12-m onth rolling time period, using a method acceptable to the AQD District Supervisor. (R 336.1702(a)) 6. The permittee shall calculate the PM and PM-10 emission rate from EG11-FCCU per 1,000 lb of coke burn off using a method acceptableMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 16 of 103



### TABLE E-1.3 {EG11-FCCU}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS
to the AQD District Supervisor. (R 336.1205), (R 336.2802), (40 CFR 52.21), (40 CFR Part 60 Subparts A & J), (40 CFR Part 63 Subparts A and UUU) 7. The permittee shall keep, in a satisfactory manner, the following monthly records for bypass lines in EG11-FCCU: a. visually inspect the seal or closure mechanism b. is the bypass line maintained in the closed position? c. is flow present in the bypass line? (40 CFR Part 63 Subparts A & UUU)

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. Particulate Matter. (40 CFR Part 60 Subparts A & J, 40 CFR Part 63 Subparts A & UUU, R 336.1213(3))

2. Carbon Monoxide. (40 CFR Part 60 Subparts A & J, 40 CFR Part 63 Subparts A & UUU, R 336.1213(3))

3. Within 180 days after commencement of trial operation of the Detroit heavy oil upgrade project, and thereafter annually, the permittee shall verify emission rates from EG11-FCCU of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days pr ior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both the filt erable and condensable fractions. For verification of PM emissions, USEPA Method 5B or 5F shall be used. (R 336.2001), (R 336.2003), (R 336.2004)

PM-10 SC II.B.6.1 (R 336.1205), (R 336.2802, 40 CFR 52.21)

PM SC II.B.1.1 (R 336.1205), (40 CFR 60.102(a)(1), 40 CFR 63.1564)

VOC 3 (R 336.1201(3)) Sulfuric acid mist (For verification of sulfuric acid mist emissions, testing shall use the cont rolled condensation method.) 3
(R 336.1201(3))

4. Within 180 days after commencement of trial operation of the Detroit heavy oil upgrade project, and at least once every five years thereafter, the permittee shall determine the VOC emission rates from EG11-FCCU by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Determination of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. Test results shall be used to calculate emissions for compliance with SC II.B.5.1. (R 336.1702, R 336.2001, R 336.2003, R 336.2004) 2. Method/Analysis 1. Reference test method deemed appropriate by the Division. (R 336.1213(3)), (R 336.1331(2))

3. Frequency and Schedule of Testing/Recordkeeping 1. As required by the Division. (R 336.1213(3))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 17 of 103



### TABLE E-1.3 {EG11-FCCU}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

IV. REPORTING
Reports and Schedules See Appendix 1.8 of RO Permit 199700013c

V. OPERATIONAL PARAMETERS 1. The permittee shall not operate EG11-FCCU unless the el ectrostatic precipitator is installed, maintained, and operated in a satisfactory manner. Satisfactory operation is described in t he Startup, Shutdown and

Malfunction Plan. (40 CFR Part 63 Subparts A & UUU, R 336.1910)

VI. OTHER REQUIREMENTS 1. Permittee shall comply with all applicable requirem ents of 40 CFR 60 as follows: Subpart A, General Subpart J, Standard of Performance for Petroleum Refineries. (40 CFR Part 60 Subparts A and J)

2. Permittee shall install, calibrate , maintain and operate continuous monitoring systems subject to the provisions of 40 CFR 60.105. (40CFR 60.105)(a))

3. An instrument for the continuous m onitoring and recording of opacity. (40 CFR 60.105(a)(1))

4. An instrument for the continuous monito ring and recording of carbon monoxide. (40 CFR 60.105(a)(2))

5. An instrument for the continuous monito ring and recording of sulfur dioxide. (40 CFR 60.104), (40 CFR 60.105(a)(3))

6. An instrument for the continuous moni toring and recording of nitrogen oxides. (40 CFR 60.104), (40 CFR 60.105(a)(3))

7. Each owner or operator required to install a continuous monitori ng device shall submit excess emissions and monitoring systems performance r eport and-or summary report form (see 40 CFR 60.7(d)) to the Department semi-annually, except when: more frequent reporting is specifically required by an applicable subpart; or the Department, on a case-by-case basis, determines that more frequent reporting is necessary to accurately assess the compliance status of the source. All reports shall be postmarked by the 30th day following the end of each six-month period. Written r eports of excess emissions shall include the following

information: (1) The magnitude of excess emissions computed in accordance with Sec. 60.13(h), any conversion factor(s) used, and the date and time of commence ment and completion of each time period of excess emissions. The process operating time during the reporting period. (2) Specific identification of each period of excess emissions that occu rs during startups, shutdowns, and malfunctions of the affected facility. The nature and ca use of any malfunction (if known), the corrective action taken or preventat ive measures adopted. (3) The date and time identifying each period during which the continuous monitoring system was inoperative except for zero and span checks and t he nature of the system repairs or adjustments. (4) When no excess emissions have occurred or the continuous monitoring system(s) have not been inoperative, repaired, or adjusted, such in formation shall be stated in the report. (40 CFR 60.7(c))

8. Permittee shall comply with all applicable reporting requirements in 40 CFR 60.7. (40 CFR 60.7)

9. Permittee shall maintain a file of all informatio n reported in the semi-annual reports and all other data collected, either by continuous monito ring system or as necessary to convert monitoring data to the units of the applicable standard, for a minimum of five years from the date of collection of such data or submission of such reports. (R 336.1213(3)(b)(ii)

10. Permittee shall comply with all applicable require ments of 40 CFR 63 as follows: Subpart A, General Subpart UUU, National Emission Standar ds for Hazardous Air Pollutants. (40 CFR Part 63, Subparts A and UUU)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 18 of 103



### TABLE E-1.3 {EG11-FCCU}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS
11. The permittee shall submit to the AQD District Superv isor, for review and approval, a Startup, Shutdown and Malfunction Plan (SSMP) for EG11-FCCU. The permittee shall not operate EG11-FCCU unless the approved SSMP, or an alternate plan approved by t he AQD District Supervisor, is implemented and maintained. The plan shall include procedures for maintaining and operating in a satisfactory manner, EG11-FCCU, add-on air pollution control device, or m onitoring equipment during malfunction events, and a program for corrective action for such events. If the SSMP fails to address or inadequately addresses an

event that meets the characte ristics of a malfunction at the time the plan is initially developed, the owner or operator shall revise the malfunction abatement plan within 45 days after such an event occurs. (40 CFR Part 63, Subparts A and UUU)

12. Along with the Notification of Compliance Status r eport, the permittee shall submit to the AQD District Supervisor, an approvable Operation, Maintenance and Monitoring plan (OMMP). The permittee shall not operate EG11-FCCU unless the approved OMMP, or an alternate plan approved by the AQD District Supervisor, is implemented. The plan shall contai n all information required by 40 CFR 63.1564(a)(3). (40 CFR Part 63 Subparts A & UUU)

13. The permittee shall install a permanent ammonia inject ion system to reduce emissions of particulate matter and oxides of nitrogen from the FCCU. Following insta llation and optimization of the installed system, permittee shall submit to the AQD District Supervisor a re quest to establish limitations for particulate matter, oxides of nitrogen and ammonia slip. 3 (R 336.1201(3), R 336.1910)

* This requirement is state enforceable only.

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 19 of 103



### EG27-ZURNBOILER 

## EMISSION UNIT CONDITIONS

DESCRIPTION Zurn Boiler. Area 27. Capacity: 210 MMBTU/hr. Fuel: Refinery fuel gas and natural gas.

Flexible Group ID: FG-HEATERS, FGDHOUPANNUAL



### POLLUTION CONTROL EQUIPMENT Multi-staged Low NOx Burner



### I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating Scenario Equipment Monitoring/ Testing

Method Underlying Applicable Requirements

1. NO X 0.20
lb/MMBTU 2 Annual rolling average* EG27-

ZURNBOILER SC II.2, VI.1 40 CFR 60.44b

2. CO 0.10
lb/MMBTU 2 Annual rolling average* EG27-

ZURNBOILER SC II.2, VI.2 R 336.1201(3)

3. PM 0.0019
lb/MMBTU 2 Three-hour average EG27-

ZURNBOILER SC II.2, V.2 R 336.1205, R 336.2802,
40 CFR 52.21

4. PM-10 0.0076
lb/MMBTU 2 Three-hour average EG27-

ZURNBOILER SC II.2, V.1 R 336.1205, R 336.2802,
40 CFR 52.21

5. VOC 0.0055
lb/MMBTU 2 Three-hour average EG27-

ZURNBOILER SC II.2, V.4 R 336.1205, R 336.1702(a)

* Annual average as determined at t he end of each calendar month.



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. Natural gas or refinery fuel gas

burned 210,000 cubic feet per hour based on 1,000
BTU/cubic foot 2 According to Method EG27-ZURNBOILER SC VI.6 R 336.1205, R 336.2802,
40 CFR 52.21

2. The permittee shall burn only refinery fuel gas or sweet natural ga s in EG27-ZURNBOILER. 2 (R 336.1205, R 336.1224, R 336.1225, R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A & Db)



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. The permittee shall comply with all provisions of the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A, Db, and J, as they apply to EG27-ZURNBOILER. 2
(40 CFR Part 60 Subparts A, Db, & J)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 20 of 103



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. The heat input for EG27-ZURNBOILER sha ll not exceed 210 MMBTU/hr on a daily average. 2 (R 336.1205, R 336.1225, R 336.1702(a), R 336.2802, 40 CFR 52.21)

2. The permittee shall equip and maintain EG27-ZURNBOILER with multi-staged low-NO X burners. 2
(R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.44b)



### V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. Following issuance of this permit, but not later t han 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall verify PM-10 emission rates from EG27-ZURNBOILER by testing at owner's expense, in accordance wi th Department requirements. No less than 60 days prior to testing, t he permittee shall submit a complete test plan to the AQD. For a test conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall

demonstrate that test conditions w ill be representative of post-start up conditions. The AQD must approve the final plan prior to testing. Veri fication of emission rates includes the su bmittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both th e filterable and condensable fractions. 2 (R 336.2001, R 336.2003, R 336.2004, R 336.2803, R 336. 2804, 40 CFR 52.21(c)&(d))

2. Following issuance of this permit, but not later t han 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall verify PM emission rates from EG27-ZURNBOILER by testing at owner' s expense, in accordance with De partment requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For a test conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall

demonstrate that test conditions w ill be representative of post-start up conditions. The AQD must approve the final plan prior to testing. Veri fication of emission rates includes the su bmittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 2 (R 336.1205, R 336.2001, R 336.2003, R 336.2004)

3. Following issuance of this permit, but not later t han 180 days after commencement of trial operation of the heavy oil upgrade project and annually thereafter, the permittee shall verify PM emission rates from EG27-ZURNBOILER by testing at owner' s expense, in accordance with De partment requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For a test conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall

demonstrate that test conditions w ill be representative of post-start up conditions. The AQD must approve the final plan prior to testing. Veri fication of emission rates includes the su bmittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 2,3 (R 336.1201(3))

4. Following issuance of this permit, but not later t han 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall verify VOC emission rates from EG27-ZURNBOILER by testing at owner' s expense, in accordance with De partment requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For a test conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall

demonstrate that test conditions w ill be representative of post-start up conditions. The AQD must approve the final plan prior to testing. Veri fication of emission rates includes the su bmittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 2 (R 336.1205, R 336.1702, R 336.2001, R 336.2003, R 336.2004)

5. Following issuance of this permit, but not later t han 180 days after commencement of trial operation of the heavy oil upgrade project and annually thereafter, the permittee shall verify VOC emission rates from EG27-ZURNBOILER by testing at owner' s expense, in accordance with De partment requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For a test conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall

demonstrate that test conditions w ill be representative of post-start up conditions. The AQD must approveMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 21 of 103

the final plan prior to testing. Veri fication of emission rates includes the su bmittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 2,3 (R 336.1201(3))

6. Following issuance of this permit, but not later t han 180 days after commencement of trial operation of the heavy oil upgrade project and annually thereafter, the permi ttee shall verify sulfuric acid mist emission rates from EG27-ZURNBOILER by testing at owner's expense, in accordance wi th Department requirements. No less than 60 days prior to testing, t he permittee shall submit a complete test plan to the AQD. For a test conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall

demonstrate that test conditions w ill be representative of post-start up conditions. The AQD must approve the final plan prior to testing. Veri fication of emission rates includes the su bmittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 2,3 (R 336.1201(3))

7. For tests required by SC V.1 through 6, the follo wing applies for valid, regularly scheduled tests, conducted during normal operations: 2,3 (R 336.1201(3) a. If a test indicates non-compliance with a permitted emission rate, and the test is required to be conducted on either a three or five year cycle, the frequency of such tests shall be annual for two consecutive years. Following two consecutive years of compliance, the frequency of testing shall return to the original three or five year cycle.



### 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 install, calibrate, maintain and oper ate in a satisfactory manner a device to monitor and

record the NO X and oxygen emissions from EG27-ZURNBOILER on a continuous basis. The permittee shall install and operate the Continuous Emission Moni toring System (CEMS) in accordance with the requirements of 40 CFR §§60.11, 60.13, and Part 60, A ppendix A, the applicable performance specification test of 40 CFR Part 60 Appendices B and F. With resp ect to 40 CFR Part 60 Appendix F, in lieu of the requirements of 40 CFR Part 60 Appendix F §§5.1.1, 5. 1.3, and 5.1.4, the permitt ee shall conduct either a Relative Accuracy Audit (RAA) or a Relative Accuracy Test Audit (RATA) once every twelve (12) calendar quarters, provided that a Cylinder Ga s Audit is conducted each calendar quarter. Within 30 days following the end of each calendar quarter, the permittee shall su bmit the results to the AQD in the format of the data
assessment report. 2 (R 336.1205, R 336.2802, 40 CFR 52. 21, 40 CFR Part 60 Subparts A and Db, 40 CFR 60.48b)

2. The permittee shall install, calibrate, maintain and oper ate in a satisfactory manner a device to monitor and record the CO and oxygen emissions from EG27-ZUR NBOILER on a continuous basi s. The permittee shall install and operate the CEMS in accordance with th e requirements of 40 CFR §§60.11, 60.13, and Part 60, Appendix A, the applicable performance specification test of 40 CFR Part 60 Appendices B and F. With respect to 40 CFR Part 60 Appendix F, in lieu of the requirements of 40 CFR Part 60 Appendix F §§5.1.1, 5.1.3, and 5.1.4, the permittee shall conduct either a Relative Accuracy Audit (RAA) or a Relative Accuracy Test Audit (RATA) once every twelve (12) calendar quarters, provided that a Cylinder Gas Audit is conducted each calendar quarter. Within 30 days foll owing the end of each calendar quarter, the permittee
shall submit the results to the AQD in th e format of the data assessment report. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

3. Permittee shall monitor and keep records of the co ncentration of hydrogen sulfide in the refinery fuel gas

burned in EU27-ZURNBOILER in accordance with the Fede ral Standards of Performance as specified in 40 CFR 60, Subpart J, in a manner and with instrumentati on acceptable to the Division. Fuel gas combustion devices having a common source of fuel gas may be m onitored at only one location, if monitoring at this location accurately represents the concentration of H 2 S in the fuel gas being burned. 2
(40 CFR 60.105(a)(4))

4. The permittee shall monitor emissions and operati ng information for EU27-ZURNBOILER in accordance

with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A, Db, and J. 2 (R 336.1205, 40 CFR Part 60 Subparts A, Db, & J)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 22 of 103

5. The permittee shall keep records of emissions an d operating information to comply with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A, Db, and J. The permittee shall keep all source emissions da ta and operating information on file at the facility and make them available to the Department upon request. 2 (R 3361205, 40 CFR Part 60 Subparts A, Db, & J)

6. The permittee shall install, calibrate, maintain and oper ate in a satisfactory manner a device to monitor and record the natural gas and refinery fuel gas usag e rate in EU27-ZURNBOILER on an hourly basis. The permittee shall determine the heat value of the gas bur ned in Btu per cubic foot on a monthly basis from samples taken at a point in the pipeline to EU27-ZU RNBOILER on the permittee's property. Upon request, the AQD District Supervisor may authorize a differe nt sampling schedule. Each day, the permittee shall determine the heat input rate to EU27-ZU RNBOILER for the previous operating day. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)



### VII. REPORTING

NA



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. SV27-BR7 72 150 R 336.1225



### IX. OTHER REQUIREMENT(S)

1. The permittee shall comply with all applicable provis ions of the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subpa rt A-General Provisions, Subpart Db-Standards of

Performance for Industrial-Commercial-Institutional Steam Generating Units, and Subpart J-Standards of

Performance for Petroleum Refineries , as they apply to EG27-ZURNBOILER. 2 (40 CFR Part 60 Subparts A, Db, and J)

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).

3 This condition is included at the request of the permittee.



### TABLE E-1.15 {EU27-B&WBOILER1}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

EMISSION GROUP Gas-fired boiler, capacity: 200,000 pounds steam per hour at 600 psig; design heat input not to exceed 300 MMBt u/hr. Fuel: Refinery fuel gas and natural gas. Flexible Grouping ID FG-HEATERS, FGDHOUPANNUAL

I. DESIGN PARAMETERS

A. Pollution Control Equipment Low NOx Burner, Flue Gas Recirculation system.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 23 of 103



### TABLE E-1.15 {EU27-B&WBOILER1}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

B. Stack/Vent Parameters Exhaust gases shall be discharged unobstructed vertically upwards unless

otherwise noted.

Stack/Vent ID a. Minimum

Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp

(°F) d.

Air Flow

Rate (acfm) Applicable Requirement

1. SV-B&WBOILER1 150 63 NA NA R 336.1225
C. Other Design Parameters
1. The maximum heat input in the boiler shall not exceed 300 million BTUs per hour. (R 336.1801, 40 CFR Part 60 Subpart Db) 2. Permittee shall only burn sweet natural gas or refinery fuel gas as fuel for the boiler. (R 336.1201(3), R 336.2802, 40 CFR Part 60 Subpart Db, 40 CFR 52.21)

II. MATERIAL USAGE/EMISSION LIMITS
A. Material Maximum Usage Rate
1. Natural Gas or refinery fuel

gas 1. 300,000 cubic feet per ho ur based on 1,000 BTU/ft3 (R 336.1801, 40 CFR Part 60 Subpart Db)

B. Pollutant Maximum Emission Limit
1. Nitrogen Oxide (NOx)

emissions 1. 0.20 pounds per million BTUs heat input, based upon a 24-hour

average. (R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subpart Db) 2. 0.05 pounds per million BTUs heat input, based on an annual rolling average, as determined at the end of each calendar month. 3
(R 336.1201(3)) 2. Carbon monoxide (CO)

emissions 1. 400 ppmv (1) , based upon a 24-hour average (R 336.1201(3)) 2. 0.028 pounds per million BTUs heat input, based on an annual rolling average, as determined at the end of each calendar month. 3
(R 336.1201(3)) 3. PM-10 1. 0.0076 pounds per million BTUs heat input, based upon a three-hour

average. (R 336.1205) 4. PM 1. 0.0019 pounds per million BTUs heat input, based upon a three-hour

average. (R 336.1205) 5. VOC 1. 0.0055 pounds per million BTUs heat input, based on a three-hour rolling average. (R 336.1205, R 336.1702(a))
6. Sulfur dioxide (SO 2 )

emissions 1. The H 2 S content of the refinery fuel gas shall not exceed 160 ppmv on a 3 hour rolling aver age basis. (40 CFR 60.104(a)(1))

(1) @ 3 % excess oxygen

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDKEEPI NG (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. Nitrogen Oxide emissions. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subpart Db)

2. CO (R 336.1205, R 336.2802, 40 CFR 52.21)

3. Oxygen. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subpart Db)

4. The permittee shall install, certify, calibrate, maintain, and operate the CEMS in accordance with the requi rements of 40 CFR §§60.11, 60.13, and Part 60, Appendix A, the applicabl e performance specification test of 40 CFR Part 60 Appendices B and F. With respect to 40 CFR Part 60 Appendix F, in lieu of the requirements of 40 CFR Part 60 Appendix FMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 24 of 103



### TABLE E-1.15 {EU27-B&WBOILER1}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS
§§5.1.1, 5.1.3, and 5.1.4, the permi ttee shall conduct either a Relative Accuracy Audit (RAA) or a Relative Accuracy Test Audit (RATA) once every twelve (12) calendar quarters, provided that a Cylinder Gas Audit is conducted each calendar quarter. Within 30 days following the end of each calendar quarter, the permittee shall submit the results to the AQD in the format of the data assessment report.

2. Process Monitoring System and Recordkeeping 1. Records of emissions and operating information is required to comply

with the federal Standards of Perf ormance for New Stationary Sources as specified in 40 CFR Part 60, Subparts A, Db, and J. All source emissions data and operating data shall be kept on file for a period of at least five years and made available to the Department upon request. (R 336.1205, 40 CFR Part 60 Subpart A, Db and J)

2. Records of emissions are required . All source emissions data shall be kept on file for a period of at l east five years and made available to the Department upon request. (R 336.1205, R 336.2802, 40 CFR 52.21) 3. Other Monitoring and/or Recordkeeping 1. Hourly records of fuel consumption and firing rate. (R 336.1205, 40 CFR Part 60 Subpart Db)
B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. NA

2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. NA

IV. REPORTING
Reports and Schedules

V. OPERATIONAL PARAMETERS
1. Permittee shall not operate the boiler unless the lo w NOx burners are installed and operating properly. ( R 336.1205, R 336.1901, 40 CFR 52.21(c) and (d), 40 CFR Part 60)

3. Permittee shall not operate EU27-B&WBOILER1 at firing rates of 50 to 300 MMBtu/hr heat input unless the Flue Gas Recirculation system is installed, main tained, and operated in a satisfactory manner. (R 336.1205, R 336.1224, R 336.1225, R 336.1901, R 336.2802, 40 CFR 52.21, 40 CFR Part 60)

VI. OTHER REQUIREMENTS
1. Permittee shall comply with all applicable requir ements of 40 CFR Part 60-Standards of Performance for New Stationary Sources, Subpart A-General Provisions, Subpart Db-Standards of Performance for Industrial-Commercial-Institutional Steam Generating Units, and Subpart J-Standards of Performance for

Petroleum Refineries. (40 CFR Part 60 Subpart A, Db, J)

* This requirement is state enforceable only.

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 25 of 103



### TABLE E-1.23 {EG42-43SULRECOV}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

EMISSION GROUP Three Claus Sulfur Recovery Trains , two SCOT Tailgas Treating Units and one Thermal Oxidizer (subject to 40 CFR 60, Subpart J) Flexible Grouping ID FG-PROCUNITS, FGDHOUPANNUAL

I. DESIGN PARAMETERS A. Pollution Control Equipment Thermal Oxidizer (Incinerator)

B. Stack/Vent Parameters Exhaust gases shall be discharged unobstructed vertically upwards unless

otherwise noted.

Stack/Vent ID a.

Minimum

Height (feet) b.

Maximum

Exhaust

Dimension

(inches) c. Temp

(°F) d.

Air Flow

Rate (acfm) Applicable Requirement

1. SV43-H2 199.5 42.5 NA NA R 336.1225 R 336.1226(d) C. Other Design Parameters
1. The maximum heat input in the thermal oxidizer sha ll not exceed 25 million BTUs per hour or 219,000 millio n BTUs per year. (R 336.1205, R 336.1702, R 336.2802, 40 CFR 52.21)

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate
1. Natural gas in the thermal oxidizer 1. 25,000 cubic feet per hour based on 1,000 Btu/scf. (R 336.1225, 40 CFR 52.21)

1. NA 1. NA

B. Pollutants Maximum Emission Limit

1. Sulfur dioxide emissions from the

thermal oxidizer that controls the tail gas treatment units, No. 1 and

No. 2. 1. 250 Parts per million by volume at zero percent oxygen on a dry

basis. (40 CFR 60.104(a)(2)) 2. 175 Parts per million by volume at zero percent oxygen on a dry basis on an annual rolling average, as determined at the end of each

calendar month. 3 (R 336.1201(3)) 2. Nitrogen oxide emission rate from

the thermal oxidizer 1. 7.5 pounds per hour (R 336.1205, R 336.2802, 40 CFR 52.21)

3. Carbon monoxide emission rate

from the thermal oxidizer 1. 0.04 lb/MMBTU, based on a three-hour average. (R 336.2802, 40 CFR 52.21)

4. Particulate matter emission rate

from the thermal oxidizer 1. 0.08 lb/MMBTU. (R 336.1205, R 336.2802, 40 CFR 52.21)

5. PM10 emission rate from the

thermal oxidizer 1. 0.08 lb/MMBTU. (R 336.2802, 40 CFR 52.21)

6. Volatile organic compound

emission rate from the thermal

oxidizer 1. 0.0055 lb/MMBTU. (R 336.1205, R 336.1702, R 336.2802, 40 CFR 52.21)

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. SO2 continuous emissions (CEMS). (R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A and J) 2. Oxygen. (R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A and J) 3. The permittee shall install, certify, calibrate, maintain, and operate the
CEMS in accordance with the requirements of 40 CFR §§60.11, 60.13, and Part 60, Appendix A, the applicable performance specification test of 40 CFR Part 60 Appendices B and F. (R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A and J)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 26 of 103



### TABLE E-1.23 {EG42-43SULRECOV}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. Daily combined amount of sulfur pr oduced in the sulfur recovery units A, B and C, in long tons. (R 336.1201(3)) 2. Long tons of sulfur produced per day, on a 12-month rolling average, in sulfur recovery units A, B and C combined. (R 336.1201(3)) 3. Temperature from the thermal oxidizer in a continuous manner with instrumentation acceptable to the division. (R 336.1201(3) 4. Amount of natural gas usage in the thermal oxidizer. (R 336.1225) 5. Emissions and operating information in accordance with the federal

Standards of Performance for New St ationary Sources as specified in 40 CFR Part 60, Subparts A and J. (40 CFR 60.105, 40 CFR Part 60 Subparts A and J)
B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. Sulfur dioxide concentration. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A and J)

2. Within 180 days after commencement of trial operation and every five years thereafter, the permittee shall verify NO X emission rates from EG42-43SULRECOV by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.1205, R 336.2001, R 336. 2003, R 336.2004, R 336.2802, 40 CFR 52.21)

3. Within 180 days after commencement of trial operation and every five years thereafter, the permittee sha ll verify CO emission rates from EG42-43SULRECOV by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.2001, R 336.2003, R 336. 2004, R 336.2802, 40 CFR 52.21)

4. Within 180 days after commencement of trial operation and every five years thereafter, the permittee shall verify PM-10 emission rates from EG42-43SULRECOV by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both the

filterable and condensable fractions. (R 336.2001, R 336.2003, R 336.2004, R 336.2802, 40 CFR 52.21)

5. Within 180 days after commencement of trial operation and every five years thereafter, the permittee sha ll verify PM emission rates from EG42-43SULRECOV by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing,Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 27 of 103



### TABLE E-1.23 {EG42-43SULRECOV}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS
the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.1205, R 336.2001, R 336. 2003, R 336.2004, R 336.2802, 40 CFR 52.21)

6. Within 180 days after commencement of trial operation and every five years thereafter, the permittee shall verify VOC emission rates from EG42-43SULRECOV by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.1205, R 336.1702, R 336. 2001, R 336.2003, R 336.2004, R 336.2802, 40 CFR 52.21)

7. Within 180 days after commencement of trial operation and every three years thereafter, the permittee shall verify sulfuric acid mist

emission rates from EG42-43SULR ECOV by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following

the last date of the test. 3 (R 336.1201(3))

8. For tests required by SC III.B.1.2 through 7, the following applies for valid, regularly scheduled tests, conducted during normal operations: 3
(R 336.1201(3)) a. If a test indicates non-compliance with a permitted emission rate, and the test is required to be conducted on either a three or five year cycle, the frequency of su ch tests shall be annual for two consecutive years. Followi ng two consecutive years of compliance, the frequency of testing shall return to the original three or five year cycle.

2. Method/Analysis 1. Method s acceptable to division. (40 CFR Part 60 Subparts A and J) 2. Methods acceptable to division. (R 336.1205, R 336.2001, R 336.2003, R 336.2004, R 336.2803, R 336.2804) 3. Methods acceptable to division. (R 336.2001, R 336.2003, R 336.2004, R 336.2804) 4. Methods acceptable to division. (R 336.2001, R 336.2003, R 336.2004, R 336.2803, R 336.2804) 5. Methods acceptable to division (R 336.1205, R 336.2001, R 336.2003, R 336.2004) 6. Methods acceptable to division. (R 336.1205, R 336.1702, R 336.2001, R 336.2003, R 336.2004) 3. Frequency and Schedule of Testing/Recordkeeping 1. As required by the division. (40 CFR Part 60 Subparts A and J) 2. As required by the division. (R 336.1205, R 336.2001, R 336.2003, R 336.2004) 3. As required by the division. (R 336.2001, R 336.2003, R 336.2004)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 28 of 103



### TABLE E-1.23 {EG42-43SULRECOV}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS
4. As required by the division. (R 336.2001, R 336.2003, R 336.2004) 5. As required by the division. (R 336.1205, R 336.2001, R 336.2003, R 336.2004) 6. As required by the division. (R 336.1205, R 336.1702, R 336.2001, R 336.2003, R 336.2004)

IV. REPORTING
Reports and Schedules 1. The permittee sh all not operate EG42-43SULRECOV unless the approved Operation, Maintenance and Monitoring Plan, or an alternate plan approved by the AQD District Supervisor, is implemented. The plan shall contain all information required by 40 CFR 63.1564(a)(3). (40 CFR 63.1564(a)(3)

V. OPERATIONAL PARAMETERS
1. Permittee shall not produce more than a monthly average 145 long tons of sulfur per day, nor more than 100 long tons of sulfur per day on a rolling 12-month average, in the sulfur recovery units A, B and C combined. (R 336.1201(3))

2. Permittee shall not operate the sulfur recovery un its A, B, and C and the tail gas treatment units No. 1 and No. 2, unless the thermal oxidizer and oxygen analyzer are installed and operating properly. (R 336.1205, R 336.1224, R 336.1 225, R 336.1702, R 336.2802, 40 CF R 52.21, R 336.1901, R 336.1910, 40 CFR 60.104(a)(2)(i))

3. Permittee shall not operate the sulfur recovery uni ts A, B, and C and the tail gas treatment units No. 1 and No. 2, unless a minimum temperature of 1,200 degree s Fahrenheit and a minimum retention time of 2.0 seconds in the thermal oxidizer is maintained. Following both the promulgation of Subpart Ja in 40 CFR Part 60 and the successful completion of a stack test pursuant to that Subpart, and upon written approval by the AQD District Supervisor, the temperature and ret ention time requirements of this condition will be superseded by the temperature and retention time demons trated during the stack test and stated in the written approval. (R 336.1205, R 336.1224, R 336.1225, R 336.1 702, R 336.2802, 40 CFR 52.21, R 336.1901, R 336.1910, 40 CFR 60.104(a)(2)(i))

4. Permittee shall not operate the sulfur recovery uni ts A, B, and C and the tail gas treatment units No. 1 and No. 2, unless provisions of the F ederal Standards of Performance for Ne w Source Stationary Sources, 40 CFR Part 60, Subpart J-Standards of Perform ance for Petroleum Refineries, are met. (40 CFR Part 60 Subparts A & J)

5. The permittee shall submit to the AQD District Superv isor, for review and approval, a Startup, Shutdown and Malfunction Plan (SSMP) for EG42-43SULRECOV. The permittee shall not operate EG42-43SULRECOV unless the approved SSMP, or an alternate plan approved by the AQD District Supervisor, is implemented and maintained. The plan shall include procedures for maintaining and operating in a satisfactory manner, FG42-43SULRECOV, add-on air pollution control device, or monitoring equipment during malfunction events, and a program for corrective action for such events. If the SSMP fails to address or inadequately addresses

an event that meets the charac teristics of a malfunction at the time t he plan is initially developed, the owner or operator shall revise the malfunction abatement pl an within 45 days after such an event occurs. (40 CFR Part 63, Subparts A and UUU)

VI. OTHER REQUIREMENTS
1. Monitoring and recording of sulfur dioxide concentration and operating info rmation is required to comply with
the Federal Standards of Performance for New Stationary Sources as specif ied in 40 CFR, Part 60, Subparts

A and J. All source emissions data and operating data shall be submitted to the Division in an acceptable format within 30 days following the end of the quarter in which data were collected. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A and J, 40 CFR 60.105(a)(5))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 29 of 103



### TABLE E-1.23 {EG42-43SULRECOV}

EMISSION UNIT/PROCESS GROUP REQUIREMENTS

2. Permittee shall comply with all the applicable requir ements of 40 CFR Part 60: Standards of Performance for New Sources, Subpart A-General Provisions. (R 336.1213(3), (40 CFR Part 60, Subpart A)

3. Permittee shall comply with all applicable requirements of 40 CFR Part 63, Subpart UUU-National Emission
Standards for Hazardous Air Pollutants for Petroleum Refi neries: Catalytic Cracking Units, Catalytic Reforming Units, and Sulfur Recovery Units. (R 336.1213(3)), (40 CFR 63, Subpart UUU) * This requirement is state enforceable only.

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 30 of 103



## EG70-COKER

EMISSION UNIT CONDITIONS

DESCRIPTION

The Coker converts Vacuum Resid (Crude Vacuum Towe r Bottoms), a product normally sold as asphalt or blended into residual fuel oil, into lighter, more val uable products. The Vacuum Resid feedstock is heated before it enters the main fractionator, where lighter mate rial vaporizes. The fractionator bottoms are routed through a fired heater and then into a coke drum. This emi ssion unit consists of proc ess vessels (fractionators), coke drums, heater, cooling tower, compressors, pumps, piping, drains, & various components (pumps & compressor seals, process valves, pressure relief va lves, flanges, connectors, etc.). This emission group includes the Coke Handling System, which will collect, si ze, and transport the petroleum coke created during the coking process. This system consists of a coke pit, storage pad, enclosed crushe r, enclosed conveyors, and surge bins. Other EG’s were created to address individual pieces of equipment within th is unit that have specific applicable requirements.

Flexible Group ID: FGDHOUPANNUAL



### POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. Visible

emissions No visible

emissions 2 According to method Truck loading; weigh bins; and the coke handling system beginning with the enclosed conveyor leading to the crusher. SC VI.2 R 336.1301

2. VOC 20 tpy 2 According to method Exhaust from coke

drum steam vent. SC VI.8 R 336.1702

3. PM 1.0 tpy 2 According to method Exhaust from coke

drum steam vent. SC VI.8 R 336.1205, R 336.2802,
40 CFR 52.21

4. H2S 0.7 tpy 1 According to method Exhaust from coke

drum steam vent. SC VI.8 R 336.1224, R 336.1226(d)



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. Moisture

content of coke Minimum 6% by weight 2 According to method Coke handling operations after the

coke has been

removed from the

coke drum. SC VI.3 R 336.1205, R 336.2802,
40 CFR 52.21

2. Coke production 500 tons per

hour 2 Daily average Equipment subject to
SC I.1. SC VI.4 R 336.1205, R 336.2802,
40 CFR 52.21Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 31 of 103

3. The permittee shall not recycle coker blowdown water as quench water in the coke drums. (R 336.1205, R 336.2802, 40 CFR 52.21)



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. The permittee shall not vent the active coke drum to the atmosphere until the end of the coking cycle, when the drum pressure is 2 psig or less. 2 (R 336.1205, R 336.1702, R 336.2802, 40 CFR 52.21)

2. The permittee shall not remove coke from a coke drum or handle coke after removal from a coke drum unless a program for continuous fugitive emissions control has been submitted to the AQD District Supervisor as a proposed revision to the Fugitive Dust Control Program required in Table B-1 of RO Permit 199700013c. The proposed revision shall address the fo llowing aspects of the coke handling system: all plant roadways, the plant yard, all material storage piles, and all material handling operations. The submitted program shall include, as a minimum, all of the following: a. Use of jet water sprays to empty the coke drum into a coke pit below the grade of the coke storage pad. b. Use of water sprays on any coke stockpile and during coke crushing to maintain coke moisture. c. Monitoring and correction of coke moisture to comply with SC II.1. d. Use of bridge cranes to transfer coke from the pit to a stockpile and from a stockpile to the crusher receiving hopper, except as allowed in SC III.1.e.

e. Limited use of front-end loaders or other vehicles on the coke st orage pad: only during bridge crane

maintenance or breakdown. f. Inspection, maintenance, and monitoring of a “tota lly enclosed gallery” for transporting crushed coke from the crusher to the surge/weigh bin system. The permittee shall comply with the submitted prog ram until the AQD District Supervisor approves the program or approves an amended program. Thereafte r, the permittee shall comply with the approved program. At any time, the permittee may submit a m odified program to the AQD District Supervisor for review and approval. 2 (R 336.1371, R 336.1372, Act 451 324.5524)

3. The height of any coke pile on the storage pad shall not exceed the height of the perimeter wall at any

time. 2 (R 336.1301)

4. The permittee shall not operate any equipment in t he coke handling system unles s a malfunction abatement plan (MAP) as described in Rule 911(2), for the coke handling system, has been submitted no less than 120 days before commencing operation of the coke handling system, and is implemented and maintained. If at any time the MAP fails to address or inadequately addr esses an event that meets the characteristics of a malfunction, the permittee shall amend the MAP within 45 days after such an event occurs. The permittee shall also amend the MAP within 45 days, if new equipm ent is installed or upon re quest from the District Supervisor. The permittee shall submit the MAP a nd any amendments to the MAP to the AQD District Supervisor for review and approval. If the AQD does not notify the permittee within 90 days of submittal, the MAP or amended MAP shall be considered approved. Until an amended plan is approved, the permittee shall implement corrective procedures or operational changes to achieve compliance with all applicable

emission limits. 2 (R 336.1205, R 336.1301, R 336.1331, R 336.1910, R 336.1911, R 336.2802, 40 CFR 52.21)

As a minimum, the MAP shall address the following: a. Maintaining required coke moisture content. b. Maintaining the integrity of all enclosures: inte gral crusher enclosure, co nveyor enclosures and the shed for truck loading. c. Surge bin dust collector.

5. The permittee shall not cycle the coke drums more than 487 times per 12-month rolling time period, as

determined at the end of each calendar month. (R 336.1205, R 336.2802, 40 CFR 52.21)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 32 of 103



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. The permittee shall equip and maintain the coker with a gas recovery system to recover the coke drum vapors and route them to the fuel gas treatment system. 2 (R 336.1205, R 336.1702)

2. The permittee shall equip and maintain the coker with instrumentation to monitor the pressure in the coke drum during coking cycles. 2 (R 336.1205, R 336.1702)

3. The permittee shall equip and maintain the coke storage area with a pit below the grade of the coke storage pad and with perimeter walls no less than 30 feet above the level of the coke storage pad. 2 (R 336.1301)

4. The permittee shall not convey crushed coke to the surge bins unless the totally enclosed conveyors and surge bin dust collector are installed, main tained, and operated in a satisfactory manner. 2 (R 336.1910)

5. The permittee shall not load trucks with crushed co ke unless the surge bin dust collector is installed, maintained, and operated in a satisfactory manner. 2 (R 336.1910)



### V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. Within 180 days after commencement of trial op eration of EG70-COKER, and annually thereafter, the permittee shall determine VOC, PM, and H 2 S emission rates from the coke dr um steam vent by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Determination of emission rates includes the subm ittal of a complete report of the test results to the AQD within 60 days following the last date of the test. At any time after completing five tests acceptable to the AQD District Supervisor, the permi ttee may request that the testing freq uency be reduced. If the testing frequency is reduced, testing shall be conducted no less often than once every five years. Test results shall be used to calculate emissions as required by SC VI .8, and to determine compliance with the requirements
for FGDHOUPANNUAL. 2 (R 336.1205, R 336.1224, R 336.1702, R 336.2001, R 336.2003, R 336.2004, R 336.2802, 40 CFR 52.21)

2. For tests required by SC V.1, the following applie s for valid, regularly scheduled tests, conducted during normal operations: 3 (R 336.1201(3)) a. If a test indicates non-compliance with a permitted emission rate, and the test is required to be conducted on either a three or five year cycle, the frequency of such tests shall be annual for two consecutive years. Following two consecutive years of compliance, the frequency of testing shall return to the original three or five year cycle.

See Appendix 1.5 of RO Permit 199700013c



### 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 keep, in a satisfactory manner, a record of the coke drum pressure at which the active drum is vented to the atmosphere. 2 (R 336.1205, R 336.1702)

2. The permittee shall verify the absence of visible em issions by taking six-minute visible emission readings for the equipment listed in SC I.1 a minimum of once per calendar day. The reader shall take each visible emission reading during routine operating conditions. Fo r purposes of this condition, the opacity reading is not required to use Method 9. If the permittee obs erves any visible emissions, the permittee shall immediately initiate corrective actions. 2 (R 336.1301)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 33 of 103

3. The permittee shall monitor, in a satisfactory manne r, the moisture of the coke on the coke storage pad and other non-enclosed areas on a daily basis, as provi ded in the approved fugitive dust control program for
EG70-COKER. 2 (R 336.1205, Act 451 324.5524)

4. The permittee shall keep, in a satisfactory manner, a daily record of the amount of coke loaded onto trucks for shipping. 2 (R 336.1205)

5. The permittee shall keep, in a satisfactory manner, da ily records of coke moisture, as required by SC VI.2. 2
(R 336.1205, Act 451 324.5524)

6. The permittee shall keep, in a satisfactory manner, records of all visible emis sion readings required by SC VI.2. At a minimum, records shall include the date, time, name of observer/reader, and status of visible

emissions. 2 (R 336.1301)

7. Within 30 days after completion of the installati on of EG70-COKER, the permittee or the authorized agent pursuant to Rule 204 shall notify the AQ D District Supervisor, in writing, of the completion of the activity. Completion of the installation, construction, reconstructi on, relocation, or modification is considered to occur not later than commencement of trial operation of EG70-COKER. 2 (R 336.1216(1), R 336.1201(7)(a))

8. The permittee shall calculate the VOC, PM, and H 2 S emission rates from the coke drum steam vent monthly, for the preceding 12-month rolling time peri od, using a method acceptable to the AQD District Supervisor. As soon as test results acceptable to the AQD District Supervisor are available from the testing required by SC V.1, the permittee shall use emission factors derived from testing to calculate emission

rates. 2 (R 336.1205, R 336.1224, R 336 .1702, R 336.2802, 40 CFR 52.21)

9. The permittee shall keep, in a satisfactory manner , records of the number of times the coke drums are cycled for each month and for each 12-month rolling time period as dete rmined at the e nd of each calendar

month. (R 336.1205, R 336.2802, 40 CFR 52.21)



### VII. REPORTING

1. NA



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. Coke Drum Vent (unobstructed vertical discharge not required) not restricted 222 1 R 336.1225, R 336.1226(d)



### IX. OTHER REQUIREMENT(S)

1. NA

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).

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 34 of 103



## EG-COKERFLARE

EMISSION GROUP CONDITIONS

DESCRIPTION

Coker Plant Flare. Area 76

Flexible Group ID: FGDHOUPANNUAL



### POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA NA NA NA NA NA



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA NA NA NA NA NA



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. The permittee shall install a coker blowdown gas recovery system upstream of EG-COKERFLARE to recover and route coke drum vent gas to the fuel gas treatment system. (R 336.1205, R 335.1224, R 336.1702, R 336.2802, 40 CFR 52.21)

2. The permittee shall equip and maintain the coker bl owdown gas recovery system with redundant recovery compressors, each designed with the capacity to individually recover all coke drum vent gases. (R 336.1205, R 335.1224, R 336. 1702, R 336.2802, 40 CFR 52.21)

3. At least 60 days prior to initial startup of the Detr oit heavy oil upgrade project, the permittee shall submit to MDEQ a demonstration showing that t he coker blowdown gas recovery system is sized appropriately for the coke drums. The demonstration shall include the following elements: a. The design capacity of the coker blowdown gas recovery system and design specifications of components, such as the compressors. b. Description of extra capacity and redundancies desi gned into the coker blowdown gas recovery system. c. An explanation of the assumptions made in determi ning the appropriate design capacity of the coker blowdown gas recovery system.
d. Confirmation that no cross-over points exist between the coker blowdown gas recovery system and any fuel gas systems outside of it. (R 336.1205, R 335.1224, R 336. 1702, R 336.2802, 40 CFR 52.21)



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. NAMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 35 of 103



### 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 install, maintain, and continuo usly operate a continuous flow measuring device to continuously monitor and record the flow of gas to the fl are. The flow measuring device shall be sensitive to rapid flow changes, and have the capability of reportin g both instantaneous velocity and totalized flow. Materials exposed to the flare gas shall be corrosion re sistant. The flow measuring device shall (i) feature automated daily calibrations at low and high ranges, and (ii) shall signal alarms if the calibration error or drift is exceeded, provided that the monitor is equipped with such capability. The volumetric flow measuring device may consist of one or more flow meters, and, as combined, shall meet the following specifications. (R 336.1205, R 335.1224, R 336. 1702, R 336.2802, 40 CFR 52.21) a. Velocity Range: 0.1-250 ft/sec b. Repeatability: ± 1% of read ing over the velocity range c. Accuracy: ± 20% of readi ng over the velocity range of 0.1-1 ft/s and ± 5% of reading over the velocity range of 1-250 ft/s d. Installation: Applicable AGA, ANSI, API, or equivalent standard. e. Flow Rate Determination: Must be corrected to one atmosphere pressure and 68 °F and recorded as one-minute averages. f. Data Records: Measured continuously and record ed over one minute averages. The instrument shall be capable of storing or transferring all data for later retrieval. g. QA/QC: An annual verification of accuracy is required, and shall be specified by the manufacturer.

2. All data as generated by the flow measuring device shall be continuousl y recorded. The recording system must have the capability to generate o ne-minute average data from that wh ich is continuous ly generated by the flow measuring device. (R 336.1205, R 335.1224, R 336.1702, R 336.2802, 40 CFR 52.21)

3. The permittee shall maintain the flow measuring de vice in good operating condition at all times when the flare that it serves is operational, except when out of service due to: a. Breakdowns and unplanned system maintenance, wh ich shall not exceed 96 hours, cumulatively, per quarter for each reporting period; or, b. Planned maintenance, which shall not exceed 14 da ys per 18 month period, provided that a written notification detailing the reason for maintenance and methods that will be used during the maintenance period to determine emissions associated with flare events is provided to the AQD District Supervisor prior to, or within 24 hours of, removal of the monitoring system from service. (R 336.1205, R 335.1224, R 336. 1702, R 336.2802, 40 CFR 52.21)



### VII. REPORTING

1. At least 60 days prior to initial startup of the DHOU P, the Permittee shall submit to Michigan DEQ drawings identifying the location of the flow m easuring device required by SC VI.1. (R 336.1205, R 335.1224, R 336.1702, R 336.2802, 40 CFR 52.21)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 36 of 103



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. NA NA NA NA



### IX. OTHER REQUIREMENT(S)

1. NA

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).Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 37 of 103



## EG72-SULRBLOCK2

EMISSION UNIT CONDITIONS

DESCRIPTION

Sulfur Block 2. Area 72. The Sulfur Block removes hydrogen sulfide from ac id gas and converts it to elemental sulfur using Claus Process (Trains D and E), the SCOT Tail Gas Treating Unit process (Trains No. 3 and No. 4), and associated amine treating equipment. The exhaust tail gas is routed to a thermal oxidizer. This emission group consists of process vessels (including thermal reactors, an absorbing tower, and a stripping tower), heaters, tanks, containers, compressor s, seals, process valves, flanges, connectors, etc.). Other EG’s have

been created to address individual units whic h have specific applicable requirements.

Flexible Group ID: FGDHOUPANNUAL



### POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing

Method Underlying Applicable Requirements

1. NO X 0.2
lb/MMBTU 2 According to method EG72-

SULRBLOCK2 SC V.1 R 336.1205, R 336.2802,
40 CFR 52.21

2. SO 2 250 ppmv 2 According to method EG72-

SULRBLOCK2 SC VI.1 40 CFR 60.104(a)(2)(i)

3. SO 2 100 ppmv at 0% oxygen 3 Annual rolling average EG72-

SULRBLOCK2 SC VI.1 R 336.1201(3)

4. CO 0.04
lb/MMBTU 2 According to method EG72-

SULRBLOCK2 SC V.2 R 336.1205, R 336.2802,
40 CFR 52.21

5. PM 0.08
lb/MMBTU 2 According to method EG72-

SULRBLOCK2 SC V.4 R 336.1205, R 336.2802,
40 CFR 52.21

6. PM-10 0.08
lb/MMBTU 2 According to method EG72-

SULRBLOCK2 SC V.3 R 336.1205, R 336.2802,
40 CFR 52.21

7. VOC 0.0055
lb/MMBTU 2 According to method EG72-

SULRBLOCK2 SC V.5 R 336.1205, R 336.1702(a), R 336.2802, 40
CFR 52.21



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. Elemental sulfur produced 225 long tons per day 12-month rolling average EG72-

SULRBLOCK2 SC VI.8 R 336.1205, R 336.2802, 40
CFR 52.21Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 38 of 103



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. The heat input capacity of auxiliary fuel in the thermal oxidizer of EG72-SULRBLOCK2 shall not exceed a maximum of 30 MM Btu per hour, on a daily average. 2 (R 336.1205, R 336.1702, R 336.2802, 40 CFR 52.21)

2. The heat input capacity of auxiliary fuel in the thermal oxidizer of EG72-SULRBLOCK2 shall not exceed a maximum of 25 MM BTU per hour on an annual rolling aver age, as determined at the end of each calendar

month. 2,3 (R 336.1201(3))

3. The permittee shall comply with all provisions of the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and J, as they apply to EG72-SULRBLOCK2. (40 CFR Part 60 Subparts A & J)

4. The permittee shall comply with all provisions of the National Emission Standards for Hazardous Air Pollutants as specified in 40 CFR Part 63 Subpart s A and UUU, as they apply to EG72-SULRBLOCK2. (40 CFR Part 63 Subparts A & UUU)



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. The permittee shall not operate EG72-SULRBLOCK2 unl ess the thermal oxidizer is installed, maintained and operated in a satisfactory manner. Satisfactory o peration of the thermal oxidizer includes operating the

thermal oxidizer as described in t he startup, shutdown, and malfunction plan required by 40 CFR Part 63, Subparts A and UUU. (R 336.1205, R 336.1224, R 336.1225, R 336.1702, R 336.2802, R 336.1901, R 336.1910, 40 CFR 52.21, 40 CFR 60.104(a)(2)(i))

2. The permittee shall equip and maintain the EG72-SUL RBLOCK2 sulfur pits with a properly operating degassing system to remove and capture H 2 S and TRS from the sulfur in the sulfur pits prior to transfer to the sulfur storage tanks. Gases removed and captured by the degassing system shall be returned to the
inlet of EG72-SULRBLOCK2. (R 336.1205, R 336.2802, 40 CFR 52.21)



### V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. Within 180 days after commencement of trial operat ion and every five years thereafter, the permittee shall verify NO X emission rates from EG72-SULRBLOCK2 by test ing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. 2 (R 336.1205, R 336.2001, R 336.2003, R 336.2004, R 336.2803, R 336.2804, 40 CFR 52.21, 40 CFR 60.104(a)(2)(i))

2. Within 180 days after commencement of trial operat ion and every five years thereafter, the permittee shall verify CO emission rates from EG72-SULRBLOCK2 by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. 2 (R 336.2001, R 336.2003, R 33 6.2004, R 336.2802, 40 CFR 52.21)

3. Within 180 days after commencement of trial operat ion and every five years thereafter, the permittee shall verify PM-10 emission rates from EG72-SULRBLOCK2 by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. 2 For verification of PM-10 emissions, te sting shall include both the filterable and

condensable fractions. (R 336.2001, R 336.2003, R 336.20 04, R 336.2802, 40 CFR 52.21)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 39 of 103

4. Within 180 days after commencement of trial operat ion and every five years thereafter, the permittee shall verify PM emission rates from EG72-SULRBLOCK2 by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. 2 (R 336.1205, R 336.2001, R 336.2003, R 336.2004)

5. Within 180 days after commencement of trial operat ion and every five years thereafter, the permittee shall verify VOC emission rates from EG72-SULRBLOCK2 by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. 2 (R 336.1205, R 336.1702, R 336.2001, R 336.2003, R 336.2004, R 336.2802, 40 CFR 52.21)

6. Within 180 days after commencement of trial operati on and every three years thereafter, the permittee shall verify sulfuric acid mist emission rates from EG 72-SULRBLOCK2 by testing at owner's expense, in accordance with Department requirements. No less t han 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 3 (R 336.1201(3))

7. For tests required by SC V.1 through 6, the follo wing applies for valid, regularly scheduled tests, conducted during normal operations: 3 (R 336.1201(3)) a. If a test indicates non-compliance with a permitted emission rate, and the test is required to be conducted on either a three or five year cycle, the frequency of such tests shall be annual for two consecutive years. Following two consecutive years of compliance, the frequency of testing shall return to the original three or five year cycle.



### 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 install, calibrate, maintain and oper ate in a satisfactory manner a device to monitor and

record the SO 2 and oxygen emissions from EG72-SULRBLOCK2 on a continuous basis. The permittee shall install and operate the Continuous Emission M onitoring System (CEMS) to meet the timelines, requirements and reporting detailed in Appendix A to this permit and shall use the CEMS data for determining compliance with SC I.2. 2 (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 60 Subparts A and J, 40 CFR 60.105(a)(5))

2. The permittee shall monitor the amount of natural gas used in the thermal oxidizer on a daily average

basis. 2 (R 336.1205, R 336.1702, R 336.2802, 40 CFR 52.21)

3. On a daily basis, the permittee s hall calculate the heat input of natural gas used in the thermal oxidizer and keep records of the fuel usage and heat input to the thermal oxidizer. 2 (R 336.1205, R 336.1702, R 336.2802, 40 CFR 52.21)

4. The permittee shall monitor emissions and operating information for EG72-SULRBLOCK2 in accordance

with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and J. 2 (R 336.1205, R 336.1225, R 336.1901, 40 CFR Part 60 Subparts A & J)

5. The permittee shall monitor emissions and operat ing and maintenance information for EG72-SULRBLOCK2

in accordance with the National Emission Standards for Hazardous Air Pollutants as specified in 40 CFR Part 63 Subparts A and UUU. (40 CFR Part 63 Subparts A & UUU)

6. The permittee shall keep records of emissions an d operating information to comply with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and J.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 40 of 103

The permittee shall keep all source emissions data and operating information on file at the facility for a period of at least five years and make them available to the Department upon request. (R 336.1205, 40 CFR Part 60 Subparts A & J)

7. The permittee shall keep records of emission inform ation and operating and maintenance information to comply with the National Emission Standards for Haza rdous Air Pollutants as specified in 40 CFR Part 63 Subparts A and UUU. The permittee shall keep all source emissions and operating and maintenance information on file at the facility for a period of at least five year s and make them available to the Department upon request. (40 CFR Part 63 Subparts A & UUU)

8. The permittee shall keep records of the long tons of elemental sulfur produced per day, on a 12-month rolling average, in EG72-SULRBLOCK2. (R 336.1205, R 336.2802, 40 CFR 52.21)

9. The permittee shall keep records of the hours per mo nth and 12-month rolling time period, as determined at the end of each calendar month, that the sulfur pit degassing system did not operate while EG72-SULRBLOCK2 was operating. (R 336.1205, R 336.2802, 40 CFR 52.21)



### VII. REPORTING

1. The permittee shall provide written notification of c onstruction and operation to comply with the federal Standards of Performance for New Stationary Sources, 40 CFR 60.7. The permittee shall submit this
notification to the AQD District Supervisor within the time frames specified in 40 CFR 60.7. 2 (40 CFR 60.7)



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. SV72-V22 96 2 150 2 R 336.1225



### IX. OTHER REQUIREMENT(S)

1. NA

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).

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 41 of 103



### Flexible Group Special Conditions

TABLE F-1.1 {FG-HEATERS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING All refinery heaters and boilers that burn refinery fuel gas. (NSPS, 40 CFR 60, Subpart J)

Emission Unit/Process Groups EG04-VACHTR, EG04-VAC2HTR, EG05-CRUDEHTR, EG08-GOHTCHARHTR, EG09-ALKYDIBREBHTR, EG11-FCCUCHARHTR, EG14-CCRPLCHARHTR, EG14-CCRPLINTHTR, EG16-NHTSTR IPREBOIL, EG16-NHTCHARHTR, EG19-KHTCHARHTR, EG22-FUELOILHTR, EG27-ZURNBOILER, EU27-B&WBOILER1, EG70-COKERHTR, EG71-H2HTR, EG77-DHTHTR Flexible Grouping ID FGDHOUPANNUAL

I. DESIGN PARAMETERS

A. Pollution Control Equipment None

B. Stack/Vent

Parameters Exhaust gases shall be discharged unobstructed vertically upwards unless

otherwise noted.

Stack/Vent ID a. Minimum Height (feet) b. Maximum Exhaust Dimension (inches) c. Temp

(°F) d. Air Flow Rate (acfm) Applicable Requirement

1. SV04-H1-05-H1 (EG04-VACHTR and EG05-CRUDEHTR) 199 118 NA NA R 336.1225

2. SV08-H1 (EG08- GOHTCHARHTR) 160 63 NA NA R 336.1225

3. SV09-H7 (EG09- ALKDIBREBHTR) 150 76 NA NA R 336.1225

4. SV11-H1 (EG11- FCCUCHARHTR) 150 90 NA NA R 336.1225

5. SV14-H4A (EG14- CCRPLINTHTR) 195 66 NA NA R 336.1225

6. SV14-H6 (EG14- CCRPLCHARHTR) 195 84 NA NA R 336.1225

7. SV16-H3 (EG16- NHTSTRIPREBOIL) 96.8 45 NA NA R 336.1225

8. SV16-H4 (EG16- NHTCHARHTR) 91.7 56 NA NA R 336.1225

9. SV19-H2 (EG19- KHTCHARHTR) 85.7 39 NA NA R 336.1225

10. SV22-1-H1 (unobstructed vertical discharge not required) (EG22-FUELOILHTR) 29.8 NA NA NA R 336.1225

11. SV04-H2 (EG04-VAC2HTR) 125 96 NA NA R 336.1225

12. SV70-H1 150 112 NA NA R 336.1225Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 42 of 103



### TABLE F-1.1 {FG-HEATERS}

FLEXIBLE GROUPING REQUIREMENTS
(EG70-COKERHTR)

13. SV77-H1 (EG77-DHTHTR) 125 60 NA NA R 336.1225

14. SV71-H1 (EG71-H2HTR) 150 192 NA NA R 336.1225

C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate
1. Hydrogen sulfide content of the refinery fuel gas burned in any

combustion device in
FG-HEATERS 1. Shall not exceed 0.10 grain per dry standard cubic foot (230 milligrams per dry standard cubic meter or 160 ppmdv ) based on a three-hour average. (R 336.1226(d)), (40 CFR 60.104(a)(1)), (40 CFR Part 60, Subparts A and J))

2. Shall not exceed 60 ppmdv based on an annual rolling average, as determined at

the end of each calendar month. 3 (R 336.1201(3))

B. Pollutants Maximum Emission Limit
1. Nitrogen oxides For each emission unit listed below that uses a nitrogen oxides (NO X ) CEMS, the lb/MMBTU limit shall be based on a 12-month rolling time period as determined at

the end of each calendar month. For ea ch emission unit listed below that does not
use a NO X CEMS, the lb/MMBTU limit shall be based on a 3-hour average.

1. EG04-VACHTR 0.05 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21), (Consent Order No. 01-40119)

2. EG05-CRUDEHTR 0.05 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21), (Consent Order No. 01-40119)

3. EG08-GOHTCHARHTR 0.05 lb/MMBTU (R 336.1205, R 336.2802), (40 CFR 52.21)

4. EG11-FCCUCHARHTR 0.05 lb/MMBTU (R 336.1205, R 336.2802), (40 CFR 52.21)

5. EG14-CCRPLCHARH TR 0.05 lb/MMBTU (R 336.1205, R 336.2802), (40 CFR 52.21)

6. EG14-CCRPLINTHTR 0.05 lb/MMBTU (R 336.1205, R 336.2802), (40 CFR 52.21)

7. EG16-NHTCHARHTR 0.20 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

8. EG16-NHTSTRIPREBOIL 0.20 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

9. EG19-KHTCHARHTR 0.20 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

10. EG22-FUELOILHTR 0.10 lb/MMBTU (R 336.1205, R 336.2802), (40 CFR 52.21)

11. EG04-VAC2HTR 0.05 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

12. EG70-COKERHTR 0.05 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

13. EG77-DHTHTR 0.05 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

14. EG71-H2HTR 0.013 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

15. EG09-ALKYDIBREBHTR 0.05 lb/MM BTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

16. EG04-VACHTR and EG05-CRUDEHTR co mbined 85 tons per year, based on a 12-month rolling time period as determined at the end of each calendarMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 43 of 103



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month. (R 336.2802), (40 CFR 52.21), (Consent Order No. 01-40119)

2. Particulate matter 1. EG71-H2 HTR 6.86 tons per year, based on a 12-month rolling time period as

determined at the end of each calendar month. (R 336.1205), (R 336.2802), (40 CFR 52.21)

2. EG71-H2HTR 0.0034 lb/MMBTU. (R 336.1205), (R 336.2802), (40 CFR 52.21)

3. Each other emission unit in FG-HEATERS 0.0019 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

3. PM10 - Particulate

matter less than 10

microns 1. EG71-H2HTR 0.010 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

2. Each other emission unit in FG-HEATERS 0.0076 lb/MMBTU (R 336.1205), (R 336.2802), (40 CFR 52.21)

4. PM2.5 - Particulate

matter less than 2.5

microns 1. EG09-ALKYDIBREBHTR 0.0076 lb/MMBTU (R 336.1205), (R 336.2903), (40 CFR Part 51 Appendix S)

5. Carbon monoxide, including periods of startup, shutdown, and

malfunction 1. EG05-CRUDEHTR 0.01 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 2. EG70-COKERHTR 0.01 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3))

3. EG11-FCCUCHARHTR 0.02 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 4. EG14-CCRPLCHARHTR 0.013 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 5. EG04-VACHTR 0.01 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3))

6. EG08-GOHTCHARHTR 0.02 lb/MMB TU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 7. EG14-CCRPLINTHTR 0.013 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 8. EG04-VAC2HTR 0.01 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 9. EG77-DHTHTR 0.02 lb/MMBTU based on an annual rolling average, as determined at the end of each calendar month. 3 (R 336.1201(3)) 10. EG16-NHTCHARHTR, EG16-NHTS TRIPREBOIL, EG 19-KHTCHARHTR, EG22-FUELOILHTR, and EG09-ALKYDIBR EBHTR 0.02 lb/MMBTU, based on a 3-hr average. (R 336.1205), (R 336.2802), (40 CFR 52.21) 11. EG71-H2HTR 13 tons per year, based on a 12-month rolling time period as

determined at the end of each calendar month. (R 336.1910) 6. Volatile organic compounds 1. Each emission unit in FG-HEATERS 0.0055 lb/MMBTU (R 336.1702)

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. Permittee shall monitor and keep re cords of the concentration of hydrogen sulfide (H2S) in the refinery fuel gas bu rned in each heater/boiler in accordance

with the Federal Standards of Performance as specified in 40 CFR 60, Subpart J, in a manner and with instrumentation acceptable to the Air Quality Division. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.105(a)(4))

2. Permittee shall monitor and keep reco rds of the concentration of total reduced sulfur (TRS) in the refinery fuel gas bu rned in each heater/boiler, in a manner and with instrumentation acceptable to the Air Quality Division. The TRS monitor may be used as an alternative to the H2S monitoring required by SC III.A.1. 3
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3. Fuel gas combustion devices having a common source of refinery fuel gas may be monitored at only one location, if monitoring at this location accurately represents the concentration of H2S or TR S in the refinery fuel gas being burned. (40 CFR 60.105(a)(4)(ii))

4. The permittee shall keep records of emissions and operating information to comply with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and J. (40 CFR Part 60 Subparts A & J)

5. Permittee shall monitor and keep reco rds of the NOx emissions from the crude

and vacuum heater stack. (SV04-H1-05-H1) (R 336.1205, Consent Order No. 01-40119)

6. The permittee shall install, certify, calibrate, maintain, and operate the NOx CEMS in requirement III.A.1.5 and an o xygen CEMS in accordance with the requirements of 40 CFR §§60.11, 60.13, and Part 60, Appendix A, the applicable performance specification test of 40 CFR Part 60 Appendices B and F. With respect to 40 CFR Part 60 Appendix F, in lieu of the requirements of 40 CFR Part 60 Appendix F §§5.1.1, 5.1.3, and 5.1. 4, the permittee shall conduct either a Relative Accuracy Audit (RAA) or a Rela tive Accuracy Test Audit (RATA) once every twelve (12) calendar quarters, provided that a Cylinder Gas Audit is conducted each calendar quarter. Within 30 days following the end of each calendar quarter, the permittee shall submit the results to the AQD in the format of the data assessment report.

7. The permittee shall install, calibrate, maintain and operate in a satisfactory
manner devices to monitor and record on a continuous basis the NO X and oxygen emissions from EG70-COKERHTR, EG08-GOHTCHARHTR, and EG71- H2HTR. The permittee shall insta ll and operate the Continuous Emission Monitoring System (CEMS) to meet t he timelines, requirements and reporting detailed in Appendix A and shall use the CEMS data for determining compliance with the appropriate emission limits in II.B.1.3, 12 & 14. (R 336.1205, R 336.2802, 40 CFR 52.21)

8. The permittee shall install, calibrate, maintain and operate in a satisfactory

manner devices to monitor and record on a continuous basis the NO X and oxygen emissions from EG14-CCRPLC HARHTR and EG14-CCRPLINTHTR. The permittee shall install and operate the Continuous Emission Monitoring System (CEMS) to meet the timelines, requirements and reporting detailed in Appendix A and shall use the CEMS data for determining compliance with the appropriate emission limits in II.B.1.4 & 5. 3 (R 336.1201(3))

9. The permittee shall install, calibrate, maintain and operate in a satisfactory manner devices to monitor and record on a continuous basis the CO and oxygen emissions from EG70-COKERHTR, EG71-H2HTR, EG08-GOHTCHARHTR, EG14-CCRPLCHARHTR, EG14-CCRPLINTHTR, EG11-FCCUCHARHTR, EG04-VAC2HTR, and EG77-DHTHTR, and, in their shared stack, EG04- VACHTR and EG05-CRUDEHTR. The perm ittee shall insta ll and operate the CEMS in accordance with the requ irements of 40 CFR §§60.11, 60.13, and Part 60, Appendix A, the applicable performance specification test of 40 CFR Part 60 Appendices B and F. With respect to 40 CFR Part 60 Appendix F, in lieu of the requirements of 40 CFR Part 60 A ppendix F §§5.1.1, 5.1.3, and 5.1.4, theMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 45 of 103



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permittee shall conduct either a Relative Accuracy Audit (R AA) or a Relative Accuracy Test Audit (RATA) once every twelve (12) calendar quarters, provided that a Cylinder Gas Audit is conducted each calendar quarter. Within 30 days following the end of each calendar quarte r, the permittee shall submit the results to the AQD in the format of the data assessment report. (R 336.1205, R 336.2802, 40 CFR 52.21)

See Appendix 1.3 of RO Permit 199700013c
2. Process Monitoring System and Recordkeeping 1. Alternate Monitoring Plan (AMP) for the Alky Unit Deethanizer off gas using hydrogen sulfide detector tubes as provided for in 40 CFR 60.13(i).

2. Alternate Monitoring Plan (AMP) for th e Propylene Unit Deethanizer off gas by daily using hydrogen sulfide detector tube s when it is being introduced directly into the refinery fuel gas system.

3. The permittee shall monitor, in a sa tisfactory manner, the heat input for each heater in FG-HEATERS, in MMBTU/hr, on a daily, monthly, and rolling 12-month time period basis. (R 336.1205(1), R 336.1225, R 336.2802, 40 CFR 52.21) 3. Other Monitoring and/or Recordkeeping 1. Daily records of the type and amount of fuel used in each heater/boiler in

FG-HEATERS (R 336.1901), (45 FR 29720)

2. The permittee shall keep, in a satisfactory manner, records of NOx emissions on a monthly and a 12-month rolling basis for EG04-VACHTR and

EG05-CRUDEHTR combined. (R 336.2802), (40 CFR 52.21), (Consent Order No. 01-40119)

3. The permittee shall keep, in a satisfacto ry manner, records of CO emissions on a monthly and a 12-month rolling basis for EG71-H2HTR. (R 336.1910)

4. The permittee shall keep, in a satisf actory manner, daily, monthly, and rolling 12-month time period records of the heat input for each heater in FG-HEATERS, in MMBTU/hr, as required by condition III.A.2.3. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)
B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be
Tested/ Recorded For any emission unit in this section required to conduct an emission test for a specific pollutant every thr ee years and every five years, the requirement to conduct an emission test every five years for that pollutant does not apply; emission testing for that emission unit for that pollut ant is required every three years.

1. Hydrogen sulfide or total reduced sulf ur concentration in refinery fuel gas. (R 336.1213(3)), (R 336. 1226(d)), (45 FR 29720)

2. Daily average heat input, in MMBTU/hr, for each unit listed in requirements V.1 through V.18. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

3. Within 180 days after commencement of trial operation of EG71-H2HTR and annually thereafter, the permittee shall ve rify emission rates from EG71-H2HTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. For verification of PM-1 0 emissions, testing shall include both the

filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

PM-10 SC II.B.3.1 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205), (R 336.2802), (40 CFR 52.21)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 46 of 103



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VOC SC II.B.6.1 (R 336.1702)

Sulfuric acid mist 3 (R 336.1201(3))

4. Within 180 days after commencement of trial operation of EG04-VAC2HTR and every five years thereafter, the permittee shall verify emission rates from EG04- VAC2HTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Ve rification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both the filt erable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

NO X SC II.B.1.11 (R 336.1205, R 336.2802, 40 CFR 52.21)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205), (R 336.2802), (40 CFR 52.21)

VOC SC II.B.6.1 (R 336.1702)

5. Within 180 days after commencement of trial operation of EG04-VAC2HTR and every five years ther eafter for sulfuric acid mist, and every three years thereafter for VOC, the permittee shall verify emission rates from EG04-VAC2HTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. (R 336.2001), (R 336.2003), (R 336.2004)

VOC 3 (R 336.1201(3))

Sulfuric acid mist 3 (R 336.1201(3))

6. Within 180 days after commencement of trial operation of EG70-COKERHTR and annually thereafter, the permittee shall verify emission rates from EG70-COKERHTR of the pollutants listed below by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Ve rification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing

shall include both the filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205), (R 336.2802), (40 CFR 52.21)

VOC SC II.B.6.1 (R 336.1702)

7. Within 180 days after commencement of trial operation of EG70-COKERHTR and every five years thereafter, the permittee shall verify emission rates from EG70-COKERHTR of the pollutants listed below by testing at ow ner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Ve rification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.2001), (R 336.2003), (R 336.2004)

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### TABLE F-1.1 {FG-HEATERS}

FLEXIBLE GROUPING REQUIREMENTS 8. Within 180 days after commencement of trial operation of EG77-DHTHTR and every five years thereafter, the permittee shall verify emission rates from EG77-DHTHTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Ve rification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing

shall include both the filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

NO X SC II.B.1.13 (R 336.1205, R 336.2802, 40 CFR 52.21)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205), (R 336.2802), (40 CFR 52.21)

VOC SC II.B.6.1 (R 336.1702)

Sulfuric acid mist 3 (R 336.1201(3))

9. Within 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall verify emission rates from EG09-ALKDIBREBHTR of the pollutant s listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both the filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

NO X applicable limits in SC II.B.1. (R 336.1205, R 336.2802, 40 CFR 52.21)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205, R 336.2802, 40 CFR 52.21)

PM-2.5 SC II.B.4.1 (R 336.1205), (R 336.2903), (40 CFR Part 51 Appendix S) CO applicable limits in SC II.B.5. (R 336.1205, R 336.2802, 40 CFR 52.21)

Sulfuric acid mist 3 (R 336.1201(3))

10. Following issuance of this permit, but not later than 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall verify emission rates from EG16- NHTCHARHTR, EG16-NHTSTRIPREBOIL, EG19-KHTCHARHTR, and EG22- FUELOILHTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall demonstrate that test conditions will be representative of post-startup conditions. The AQD must approve the final plan prior to testing. Verification of

emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both t he filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

NO X applicable limits in SC II.B.1. (R 336.1205, R 336.2802, 40 CFR 52.21)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205, R 336.2802, 40 CFR 52.21) CO applicable limits in SC II.B.5. (R 336.1205, R 336.2802, 40 CFR 52.21)

Sulfuric acid mist 3 (R 336.1201(3))

11. Following issuance of this permit, but not later than 180 days afterMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 48 of 103



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commencement of trial operation of the heavy oil upgrade project and every three years thereafter, the permittee shall verify emission rates from EG16- NHTCHARHTR and EG16-NHTSTRIPREBOIL of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall demonstrate that test conditions will be representative of post-startup conditions. The AQD must approve the final plan prior to testing. Verification of emission rates includes the s ubmittal of a complete report of the test results to the AQD wi thin 60 days following the last date of the

test. (R 336.2001), (R 336.2003), (R 336.2004)

NO X 3 (R 336.1201(3))

12. Within 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter fo r VOC, and every three years thereafter for NOx, the permittee shall verify emis sion rates from EG09-ALKDIBREBHTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last

date of the test. (R 336.2001), (R 336.2003), (R 336.2004)

NO X 3 (R 336.1201(3))

VOC 3 (R 336.1201(3))

13. Following issuance of this permit, but not later than 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall verify emission rates from EG11- FCCUCHARHTR, EG14-CCRPLCHARHTR, and EG14-CCRPLINTHTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan

shall demonstrate that test condition s will be representative of post-startup conditions. The AQD must approve the final plan prior to testing. Verification of

emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both the filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

NO X applicable limits in SC II.B.1. (R 336.1205, R 336.2802, 40 CFR 52.21)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2. (R 336.1205, R 336.2802, 40 CFR 52.21)

Sulfuric acid mist 3 (R 336.1201(3))

14. Following issuance of this permit, but not later than 180 days after commencement of trial operation of the heavy oil upgrade project and every three years thereafter, the permittee sha ll verify emission rates from EG11- FCCUCHARHTR, EG14-CCRPLCHARHTR, and EG14-CCRPLINTHTR of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan

shall demonstrate that test condition s will be representative of post-startup conditions. The AQD must approve the final plan prior to testing. Verification ofMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 49 of 103



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emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.2001), (R 336.2003), (R 336.2004)

PM 3 (R 336.1201(3))

VOC 3 (R 336.1201(3))

15. Following issuance of this permit, but not later than 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter, the permittee shall veri fy emission rates from EG04-VACHTR, EG05-CRUDEHTR, EG08-GOHTCHARHTR, and EU27-B&WBOILER1 of the pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan

shall demonstrate that test condition s will be representative of post-startup conditions. The AQD must approve the final plan prior to testing. Verification of

emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. For verification of PM-10 emissions, testing shall include both t he filterable and condensable fractions. (R 336.2001), (R 336.2003), (R 336.2004)

PM-10 SC II.B.3.2 (R 336.1205), (R 336.2802), (40 CFR 52.21)

PM SC II.B.2.1 (R 336.1205, R 336.2802, 40 CFR 52.21)

Sulfuric acid mist 3 (R 336.1201(3))

16. Following issuance of this permit, but not later than 180 days after commencement of trial operation of the heavy oil upgrade project and annually thereafter, the permittee shall verify em ission rates from EG04-VACHTR, EG05- CRUDEHTR, and EU27-B&WBOILER1 of the po llutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall s ubmit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade project, the test plan shall demonst rate that test conditions will be representative of post-startup conditions. The AQD must approve the final plan prior to testing. Verification of emission rates includes the s ubmittal of a complete report of the test results to the AQD wi thin 60 days following the last date of the

test. (R 336.2001), (R 336.2003), (R 336.2004)

PM 3 (R 336.1201(3))

VOC 3 (R 336.1201(3))

17. Following issuance of this permit, but not later than 180 days after commencement of trial operation of the heavy oil upgrade project and every five years thereafter for VOC, and every three years thereafter for PM, the permittee shall verify emission rates from EG08 -GOHTCHARHTR of th e pollutants listed below by testing at owner's expense, in accordance with Department requirements. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. For tests conducted prior to commencement of trial operation of the heavy oil upgrade pr oject, the test plan shall demonstrate that test conditions will be repr esentative of post-startup conditions. The AQD must approve the final plan prior to testing. Ve rification of emission rates includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. (R 336.2001), (R 336.2003), (R 336.2004)

PM 3 (R 336.1201(3))

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### TABLE F-1.1 {FG-HEATERS}

FLEXIBLE GROUPING REQUIREMENTS 18. For tests required by SC III.B.1, t he following applies fo r valid, regularly scheduled tests, conducted during normal operations: 3 (R 336.1201(3)) a. If a test indicates non-compliance with a permitted emission rate, and the test is required to be conducted on eit her a three or five year cycle, the frequency of such tests shall be a nnual for two consec utive years. Following two consecutive years of co mpliance, the frequency of testing shall return to the original three or five year cycle.

2. Method/Analysis 1. All testing shall be conducted using methods acceptable to the Air Quality

Division. (R 336.1213(3)), (45 FR 29720)

See Appendix 1.5 of RO Permit 199700013c 3. Frequency and Schedule of Testing / Recordkeeping 1. As requested by the Air Quality Division (R 336.1213(3))

IV. REPORTING
Reports and Schedules 1. Permittee shall submit the data on the concentration of hydrogen sulfide or total reduced sulfur in the refinery fuel gas burned in the heaters to the Air Quality Division (AQD) District Supervisor in ac ceptable format within 30 days following the end of the quarter in which the data were collected. (40 CFR 60.7)

See Appendix 1.8 of RO Permit 199700013c

V. OPERATIONAL PARAMETERS
1. The heat input to EG04-VACHTR shall not exceed 177 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

2. The heat input to EG05-CRUDEHTR shall not exceed 240 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

3. The heat input to EG08-GOHTHTR shall not exceed 115 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

4. The heat input to EG09-ALKDIBREBHTR shall not exceed 78 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

5. The heat input to EG09-ALKDIBREBHTR shall not exceed 65 MMBTU/hr on an annual rolling average, as

determined at the end of each calendar month. 3 (R 336.1201(3))

6. The heat input to EG11-FCCUCHARHTR shall not exceed 130 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

7. The heat input to EG14-CCRP LCHARHTR shall not exceed 138 MM BTU/hr on a daily average. (R 336.1205), (R 336.1225), (40 CFR 52.21)

8. The heat input to EG14-CCRPLINTHTR shall not exceed 138 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R336.2802), (40 CFR 52.21)

9. The heat input to EG16-NHTCHARHTR shall not exceed 64 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

10. The heat input to EG16-NHTSTRIPREBOIL sha ll not exceed 46 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 51 of 103



### TABLE F-1.1 {FG-HEATERS}

FLEXIBLE GROUPING REQUIREMENTS

11. The heat input to EG19-KHTCHARHTR shall not exceed 18 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

12. The heat input to EG22-FUELOILHTR shall not exceed 7.5 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

13. The heat input to EG04-VAC2HTR shall not exceed 96 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

14. The heat input to EG04-VAC2HTR shall not e xceed 46 MMBTU/hr on an annual rolling average, as

determined at the end of each calendar month. 3 (R 336.1201(3))

15. The heat input to EG70-COKERHTR shall not exceed 228 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

16. The heat input to EG70-COKERHTR shall not exc eed 209 MMBTU/hr on an annual rolling average, as

determined at the end of each calendar month. 3 (R 336.1201(3))

17. The heat input to EG77-DHTHTR shall not exceed 91 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

18. The heat input to EG77-DHTHTR shall not exceed 55 MMBTU/hr on an annual rolling average, as determined

at the end of each calendar month. 3 (R 336.1201(3))

19. The heat input to EG71-H2HTR shall not exceed 950 MMBTU/hr on a daily average. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

20. The heat input to EG71-H2HTR shall not exceed 640 MMBTU/hr on an annual rolling average, as determined

at the end of each calendar month. 3 (R 336.1201(3))

21. Except for EG71-H2HTR, the permittee shall only fire refinery fuel gas and/or sweet natural gas in FGHEATERS. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

22. The permittee shall only fire refinery fuel gas, pressure swing absorption gas, Syngas, and/or natural gas in

EG71-H2HTR. (R 336.1205), (R 336.1225), (R 336.2802), (40 CFR 52.21)

23. The permittee shall not operate EG04 -VACHTR, EG05-CRUDEHTR, EG77-DHTCHARHTR, EG08-GOHTHTR, EG11-FCCUCHARHTR, EG14-CCRPLCHARHTR, or EG14-CCRPLINTHTR unless the unit’s low NOx burners are installed, maintained, and operated in a satisfactory manner. (R 336.1205), (R 336.1910), (R 336.2802), (40 CFR 52.21)

24. The permittee shall not operate EG04-VAC2HTR , EG09-ALKDIBREBHTR, EG70-COKERHTR, or

EG77-DHTHTR unless the unit’s ultra low-NO X burners are installed, maintained, and operated in a satisfactory manner. (R 336.1205, R 336.1910, R 336.2802, 40 CFR 52.21)

25. The permittee shall not operate EG 71-H2HTR unless the selective cata lytic reduction (S CR) system is installed, maintained, and operated in a satisfactory manner. Satisfactory operation includes following the approved malfunction abatement plan. (R 336.1205, R 336.1910, R 336.2802, 40 CFR 52.21)

26. The permittee shall not operate EG71-H2HTR unless an acceptable malfunction abatement plan (MAP) for the SCR system has been submitted to the AQD District Supervisor. The plan shall include a catalyst replacement schedule based on the SCR manufacturer's recommended gui delines. If at any time the MAP fails to address or inadequately addresses an event that meets the characte ristics of a malfunction, the permittee shall amendMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 52 of 103



### TABLE F-1.1 {FG-HEATERS}

FLEXIBLE GROUPING REQUIREMENTS

the MAP within 45 days after such an event occurs. The permittee shall also amend the MAP within 45 days, if new equipment is installed or upon request from the Dist rict Supervisor. The perm ittee shall submit the MAP and any amendments to the MAP to the AQD District Super visor for review and approval. If the AQD does not notify the permittee within 90 days of submittal, the MAP or amended MAP shall be considered approved. Until an amended plan is approved, the permittee sha ll implement corrective procedures or operational changes to achieve compliance with all applicable emission limits. (R 336.1205, R 336.1224, R 336.1225, R 336.1911, R 336.2802, 40 CFR 52.21)

VI. OTHER REQUIREMENTS
1. Permittee shall comply with all requirements of the fo llowing subparts of 40 CFR Part 60: Subpart A – General and Subpart J - Standards of Performance for Petroleum Refineries. (40 CFR 60, Subparts A and J)

2. Monitoring requirements for subject emission units are shown in Appendix 3 of RO Permit 199700013c. (40 CFR 60.105)

3. Reporting and recordkeeping requirements for subject em ission units are shown in Appendix 4 of RO Permit

199700013c. (40 CFR 60.107)

4. Testing Procedures, except initial te sting, for subject emission units are shown in Appendix 5 of RO Permit

199700013c. (40 CFR 60.106)

5. No later than 180 days after startup of the new DHT heat er installed as part of the HOUP (EG77-DHTHTR), the permittee shall cease operating the exis ting DHT heater (EG07-DHTCHARHTR). (R 336.1205, R 336.2802, 40 CFR 52.21)

6. On and after startup of the heavy oil upgrade project, the permittee shall not operat e any emission unit in FG-HEATERS unless an acceptable plan that describes how emi ssions will be minimize d during all startups, shutdowns, and malfunctions has been submitted to the AQD District Supervisor and the plan is being implemented, maintained, and followed.. The plan shall incorporate procedures recommended by the equipment manufacturer as well as standard industry practices. (R 336.1205, R 336.1911, R 336.1912, R 336.2802, 40 CFR 52.21)
* This requirement is state enforceable only.

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 53 of 103



## FGFLARES

FLEXIBLE GROUP CONDITIONS

DESCRIPTION All refinery flares. Four flares are subject to the NSR Consent Decree and subsequent revisions: EG-CRUDEFLARE, EG-UNIFFLARE, EG-ALKYFLARE, and EG-CPFLARE

Emission Units: EG-CRUDEFLARE, EG-UNIFFLARE, EG-ALKYFLARE, EG-CPFLARE,

EG-COKERFLARE



### POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA

2. There shall be no visible emissions from any flare in FGFLARES except for periods not to exceed a total of five minutes during any two consecutive hours. This requirement is based on the federal Standards of Performance for New Stationary Sources, 40 CFR 60.18(c)(1). 2 (40 CFR Part 60 Subparts A and J)



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. H 2 S in refinery fuel gas burned a 160 ppmv on a 3 hour rolling average basis 2 According to method Each flare in
FGFLARES SC VI.1 40 CFR 60.104(a)(1)

a The combustion in a flare of process upset gases or fuel gas that is released to the flare as a result of relief valve leakage or other emergency malfunctions is exempt from this requirement. For flares equipped with flare gas recovery, the determination that a relief valve leakage or other emergency malfunction is exempt from this requirement will be based on the root cause analysis conducted in acco rdance with SC III.1 through 14.



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. The permittee shall comply with all provisions of the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 S ubparts A and J, as they apply to FGFLARES. 2 (R 336.1702, 40 CFR Part 60 Subparts A & J)

2. The permittee shall comply with all provisions of the National Emission Standards for Hazardous Air Pollutants as specified in 40 CFR Part 63 Subparts A and CC, as they apply to FGFLARES. 2 (R 336.1702, 40 CFR Part 63 Subparts A and CC)

3. The permittee shall conduct an event-specific investigat ion into each flaring incident that results in sulfur dioxide emissions greater than 500 pounds from FGFLAR ES in any 24-hour period. The investigation shall be performed in accordance with t he requirements outlined in Special C ondition III.11. The Permittee may rely on prior investigation reports for events that have the same or similar root causes. 2 (R 336.1205, R 336.2802, 40 CFR 52.21, U.S. EPA Consent Order 01-40119)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 54 of 103

4. The permittee shall conduct an event-specific investigat ion into each flaring incident that results in sulfur dioxide or volatile organic compound emissions gr eater than 500 pounds from FGFLARES in any 24-hour period. The investigation shall be performed in accordance with the requirements outlined in Special Condition III.12. The Permittee may rely on prior inve stigation reports for events that have the same or

similar root causes. 3 (R 336.1201(3))

5. The permittee shall maintain FGFLARES in good working order and in a manner consistent with good pollution control practices for minimizing emissions including during periods of startup, shutdown, and malfunction. Good air pollution control practice fo r FGFLARES shall include, at a minimum, development, implementation, and operation in accordance with an app roved Sulfur Shedding Plan to minimize or prevent

excess sulfur dioxide emissions from the Sulfur Recovery Units, Ta il Gas Treating Units (“TGTUs”), and associated amine system. The Sulfur Shedding Plan shall have as a goal the elimination of flaring incidents in excess of 500 pounds of sulfur dioxide in any 24-hour period through the following. 2 (R 336.1205, 40 CFR 60.11(d), U.S. EPA Consent Order 01-40119)

a. Define maintenance and operation practices for t he new Sulfur Recovery Plants, the Tail Gas Treating Units (“TGTUs”), and amine system, and associated equipment in conjunction with this project. The plan should also evaluate and addr ess any upstream process unit t hat has a direct impact on the operation and maintenance of the new Sulfur Re covery Plants, TGTUs, and Amine Systems. b. Define good air pollution control practices to minimi ze the duration and amount of excess sulfur dioxide emissions from flaring events asso ciated with the Sulfur Recovery Plants, TGTUs, and Amine Systems. The good pollution control practices shall include but not be limited to procedures to reduce excess sulfur dioxide emissions from a flaring incident th rough rate reduction or even shutdown of applicable process units associated with the flaring event. T hese practices should also entail operating measures and procedures to divert material being flared to other Sulfur Recovery Plants at the refinery. c. Define measures to ensure continuous operation of the Sulfur Recovery Plants and Amine Systems

between scheduled maintenance turnarounds. The meas ures shall include, but not be limited to, sulfur shedding procedures, adequate equipment redu ndancy, new startup and shutdown procedures, emergency procedures and schedules to coordinate maintenance turnar ounds of the Sulfur Recovery Plants, TGTUs, and any supplement al control device to coincide with scheduled turnarounds of major upstream process units.

6. The permittee shall review and revise the Sulfur Shedding Plan on at least an annual basis to ensure it

remains accurate. 2 (40 CFR 60.11(d), U.S. EPA Consent Order 01-40119)

7. The permittee shall conduct an event-s pecific investigation into each event that resulted in flaring more than 500,000 standard cubic feet of material in FGFLARES in any 24-hour period. The permitted pilot and sweep gas routed to the flares shall be excluded from the 5 00,000 standard cubic feet thre shold. The investigation shall be performed in accor dance with the requirements outlined in Special Condition III.11. The permittee may rely on prior investigation reports for event s that have the same or similar root causes. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

8. The permittee shall establish a tracking system for flar ing incidents that result in emissions greater than 100 pounds but fewer than 500 pounds of VOC from FGFLARES in any 24-hour period. The permittee will take

action to minimize the likelihood of recurrence of su ch incidents. After 28 instances of flaring events between 100 and 499 pounds of VOC within a consecutiv e twelve month period, permittee shall conduct an event-specific investigation into all such instances fo r the next six month period, at which point a new 12- month period for purposes of counting instances shall begin. 3 (R 336.1201(3))

9. The permittee shall prepare and follow a Flare Minimization Plan for FGFLARES. The plan shall be designed and implemented to reduce or eliminate flar ing events and shall include, at a minimum, the following elements. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

a. A description and technical information for each flare that includes: i. Detailed process flow diagram accurately depicti ng all pipelines, process units, flare gas recovery systems, surge drums and knock- out pots, compressors and other equipment that vent to eachMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 55 of 103

flare. At a minimum, this shall include full and accu rate as built dimensions and design capacities of the flare gas recovery systems, compre ssors, surge drums and knock-out pots. ii. Description of equipment, processes and procedures installed or implemented within the last five years to reduce flaring. The description shall specify the year of installation. iii. Description of any equipment, pr ocesses, or procedures the owner or operator plans to install or implement to eliminate or reduce flaring. T he description shall specif y the scheduled year of installation or implementation. iv. Description and evaluati on of prevention measures to address the following: 1. Flaring that has occurred or reasonably may be expected to occur during planned major maintenance activities, including startup and shutdo wn. The evaluation shall include a review of flaring that has occurred during these activities in the past five years and shall consider the feasibility of performing these activities without flaring. 2. Flaring that may reasonably be expected to occu r due to issues of gas quantity and quality. The evaluation shall include an audit of the storage ca pacity available for excess vent gases, the scrubbing capacity available for vent gases incl uding any limitations associated with scrubbing the vent gases for use as a fuel , and shall consider the feasibilit y of reducing flaring through the recovery, treatment, and use of the gas or other means. 3. Flaring caused by the recent failure of air pollution control equipment, process equipment, or a process to operate in a normal or usual manner. The evaluation shall consider the adequacy of existing maintenance schedules and protocols for such equipment. For purposes of this section,

a failure is recurrent if it occurs more than twice in any five year period as a result of the same causes as identified in the event-specific investigations. b. A program of corrective action for malfunctionin g process, air pollution control, and monitoring equipment related to the performance of FGFLARES.

c. Procedures for co nducting event-specific inve stigations as required by Conditions III.3 and III.7. d. A determination of the appropriate steam to hydroc arbon ratio for each material for each flare, the basis for the ratios, and methods for estimating emissions from each flare, including when the steam to hydrocarbon ratios are not maintained at the appropriate level.

10. The permittee shall review and revise the Flare Minimi zation Plan on at least an annual basis to that ensure it remains current and complie s with the provisions outlin ed in Special Condition III.9. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

11. At a minimum, the permittee shall include all of the following specific information in the event-specific investigations for the reportable flaring events (i.e. greater than 500 pounds SO2 or 500,000 scf of gas). 2
(R 336.1205, R 336.2802, 40 CFR 52.21 , U.S. EPA Consent Order 01-40119)

a. The date and time that the flaring event started and ended. b. The total quantity of gas flared during each event. c. An estimate of the quantity of sulfur dioxide and VOC that was emitted and the calculations used to determine the quantities. d. The steps taken to limit the duration of the flaring event or the quantity of emissions associated with the

event. e. A detailed analysis that sets forth the root cause and all significant contributing causes of the flaring

event to the extent determinable. f. An analysis of the measures, if any, available to re duce the likelihood of a recurrence of a flaring event resulting from the same root cause or sign ificant contributing causes in the future. g. A demonstration that the actions taken during the flaring event are consistent with the procedures specified in the Flare Minimization and Sulfur Shedding plans, as appropriate. If the actions taken during the flaring event are not cons istent with the procedures specif ied in the appropriate plan, then the permittee must record the actions taken for that ev ent and identify the reasons why the plan was not

followed. h. For any flaring event that last s longer than 24 hours, each calendar day shall constitute a separate

event.

12. At a minimum, the permittee shall include all of the following specific information in the event-specific investigations for the reportable flari ng events (i.e. greater than 500 pounds SO 2 or VOC, or more than 500,000 scf of gas). 3 (R 336.1201(3))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 56 of 103

a. The date and time that the flaring event started and ended. b. The total quantity of gas flared during each event. c. An estimate of the quantity of sulfur dioxide and VOC that was emitted and the calculations used to determine the quantities. d. The steps taken to limit the duration of the flaring event or the quantity of emissions associated with the

event. e. A detailed analysis that sets forth the root cause and all significant contributing causes of the flaring

event to the extent determinable. f. An analysis of the measures, if any, available to re duce the likelihood of a recurrence of a flaring event resulting from the same root cause or sign ificant contributing causes in the future. g. A demonstration that the actions taken during the flaring event are consistent with the procedures specified in the Flare Minimization and Sulfur Shedding plans, as appropriate. If the actions taken during the flaring event are not cons istent with the procedures specif ied in the appropriate plan, then the permittee must record the actions taken for that ev ent and identify the reasons why the plan was not

followed. h. For any flaring event that last s longer than 24 hours, each calendar day shall constitute a separate

event.

13. The permittee shall complete each event-specific in vestigation report within 45 calendar days after the reportable flaring incident. 2 (R 336.1205, R 336.2802, 40 CFR 52.21, U.S. EPA Consent Order 01-40119)

14. The permittee shall operate each flare in FGFLARES in a satisfactory manner at all times that emissions may be vented to it, including maintaining an adequate steam to hydrocarbon ratio in each flare and a minimum heat content of 300 BTU/scf in the vent gas to each flare. 2 (R 336.1910, 40 CFR 60.18)



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. The permittee shall equip and maintain each flare in FGFLARES with a pilot flame. 2 (R 336.1910, 40 CFR Part 60 Subpart A, 40 CFR 63.11(b)(5))

2. Each flare in FGFLARES shall be designed and installed so that it complies with the requirements of 40 CFR Part 60 Subpart A. 2 (R 336.1910, 40 CFR 60.18(c))



### V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. Within 180 days after commencement of trial operat ion of the heavy oil upgrade project, the permittee shall verify by testing, at the owner’s expense, that each flare in FGFLARES is operating within the specified velocity and heat content limits specified within 40 CFR 60.18. No less than 60 days prior to testing, the Permittee shall submit a complete test plan to the AQD. The AQD must approve the final plan prior to testing. Verification includes the submittal of a comple te report of the test results to the AQD within 60 days following the last date of the test. (R 336.1910, 40 CFR 60.18)

See Appendix 1.5 of RO permit 199700013c



### VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. Permittee shall monitor and keep records of the co ncentration of hydrogen sulfide in the refinery fuel gas

burned in each flare in accordance with the Federal Standards of Performance as specified in 40 CFR 60, Subpart J, in a manner and with instrumentation accept able to the Division. Fuel gas combustion devices having a common source of fuel gas may be monitored at only one location, if monitoring at this location accurately represents the concentration of H 2 S in the fuel gas being burned. 2 (40 CFR 60.105(a)(4))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 57 of 103

2. The permittee shall keep records of emissions and operating information for each flare in FGFLARES to comply with the federal Standards of Performance fo r New Stationary Sources as specified in 40 CFR Part 60 Subparts A and J. 2 (40 CFR Part 60 Subparts A & J)

3. The permittee shall monitor emissions and operat ing and maintenance information for each flare in FGFLARES in accordance with the National Emission Standards for Hazardous Air Pollutants as specified in 40 CFR Part 63 Subparts A and CC. 2 (40 CFR Part 63 Subparts A & CC)

4. The permittee shall keep records of emission inform ation and operating and maintenance information for each flare in FGFLARES to comply with the Nationa l Emission Standards for Hazardous Air Pollutants as specified in 40 CFR Part 63 Subparts A and CC. The permittee shall keep all source emissions and operating and maintenance information on file at the facility for a period of at least five years and make them available to the Department upon request. 2 (40 CFR Part 63 Subparts A & CC)

5. The permittee shall track and ensure timely closure of the corrective actions, if any, identified to minimize the likelihood of a recurrence of the reportable flaring ev ents. Permittee shall report every six months on the status of the yet-to-be-completed corrective acti ons related to the reportable flaring incidents. 2 (R 336.1205, R 336.2802, 40 CFR 52.21, U.S. EPA Consent Order 01-40119)

6. The permittee shall keep, in a satisfactory manner, a record of the current and prior versions of the Sulfur Shedding Plan and the Flare Minimization Plan for FGFLARES, as required by SC III.6 and III.10. The permittee shall keep all records on file at the fac ility and make them available to the Department upon request. (R 336.1205, R 336.2802, 40 CFR 52.21, U.S. EPA Consent Order 01-40119)

7. The Permittee shall monitor all flares for visible em issions using color video monitors with date and time stamp. (R 336.1205)

8. The permittee shall calculate and keep records of the annual emissions of PM, PM10, NO X , VOC, CO, SO 2 , sulfuric acid mist (H 2 SO 4 ), hydrogen sulfide (H 2 S), and Total Reduced Sulfur (TRS) from the Detroit heavy oil upgrade project (Detroit HOUP), in tons per year on a calendar year basis. Records shall be kept in the format described in Appendix B, or an alternate format acceptable to the AQD Permit Section Supervisor. Calculations and record keeping shall begin the month in which the Detroit HOUP begins normal operations and shall continue for 10 years. (R 336.2818, 40 CFR 52.21(r)(6)(iii) , 40 CFR Part 51 Appendix S)

9. The permittee shall calculate, keep records of, and annu ally report to the AQD, the annual emissions of PM, PM10, NO X , VOC, CO, SO 2 , sulfuric acid mist (H 2 SO 4 ), hydrogen sulfide (H 2 S), and Total Reduced Sulfur (TRS) from the Detroit heavy oil upgrade project (Detroit HO UP), in tons per year on a calendar year basis.

Calculations shall be based on the best available and representative data. Supporting documentation shall be submitted with the emissions report, and shall be genera lly consistent with the format and specificity of Exhibit 7 of the Sierra Club Agreement. Records shall be kept in the format described in Appendix B, or an alternate format acceptable to the AQD Permit Secti on Supervisor. Calculations and record keeping shall begin the month in which the Detroit HOUP begins nor mal operations and shall continue for 10 years. 3
(R 336.1201(3))

10. The permittee shall install, maintain, and cont inuously operate, for EG-C RUDEFLARE, EG-UNIFFLARE, EG-ALKYFLARE, and EG-CPFLARE, continuous flow me asuring devices to continuously monitor and record the flow of gas to each of these flares. The flow measuring devices shall be sensitive to rapid flow changes, and have the capability of reporting both instantaneous velocity and totalized flow. Materials exposed to the flare gas shall be corrosion resistan t. The flow measuring devices shall (i) feature automated daily calibrations at low and high ranges, and (ii) shall signal alarms if the calibration error or drift is exceeded, provided that the monitor is equipped with such capability. The volumetric flow measuring devices may consist of one or more flow meters, and, as combined, shall meet t he following specifications. (R 336.1205, R 335.1224, R 336. 1702, R 336.2802, 40 CFR 52.21) a. Velocity Range: 0.1-250 ft/sec. b. Repeatability: ± 1% of read ing over the velocity range. c. Accuracy: ± 20% of readi ng over the velocity range of 0.1-1 ft/s and ± 5% of reading over the velocity range of 1-250 ft/s. d. Installation: Applicable AGA, ANSI, API, or equivalent standard.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 58 of 103

e. Flow Rate Determination: Must be corrected to one atmosphere pressure and 68 °F and recorded as one-minute averages. f. Data Records: Measured continuously and record ed over one minute averages. The instrument shall be capable of storing or transferring all data for later retrieval. g. QA/QC: An annual verification of accuracy is required, and shall be specified by the manufacturer.

11. The permittee shall install, maintain, and continuousl y operate devices to continuously monitor and record the flow of steam to each flare in FGFLARES, the VO C composition of the vent gas stream to each flare, and the steam to hydrocarbon ratio in each flare. The monitoring devices shall meet the following specifications. (R 336.1205, R 335.1224, R 336.1702, R 336.2802, 40 CFR 52.21)

a. Turndown Ratio: 25:1. b. Repeatability: ± 1% of reading over the range of the instrument. c. Accuracy: +/- 1% from 100% to 15 % of span,+/- 2% from 15 % of span to 6 % of span, +/- 3% from 6 % of span to 4% of span. d. Installation: Applicable AGA, ANSI, API, or equivalent standard. e. Flow Rate Determination: Must be corrected to one atmosphere pressure and 68 °F and recorded as one-minute averages. f. Data Records: Measured continuously and record ed over one minute averages. The data acquisition system shall be capable of storing and transferring all data for later retrieval. g. QA/QC: An annual verification of accuracy is required, and shall be specified by the manufacturer.

12. All data as generated by the flare and steam flow measuring devices shall be continuously recorded. The recording system(s) must have the capability to gener ate one-minute average data from that which is continuously generated by the flow measuring devices. (R 336.1205, R 335.1224, R 336.1702, R 336.2802, 40 CFR 52.21)

13. The permittee shall maintain the flare and steam fl ow measuring devices and steam to hydrocarbon control system in good operating condition at all times when t he flare that it serves is operational, except when out

of service due to: a. Breakdowns and unplanned system maintenance of each monitoring device shall not exceed 96 hours, cumulatively, per quarter for each reporting period; or, b. Planned maintenance, which shall not exceed 14 da ys per 18 month period, provided that a written notification detailing the reason for maintenance and methods that will be used during the maintenance period to determine emissions associated with flare events is provided to the AQD District Supervisor prior to, or within 24 hours of, removal of the monitoring system from service. (R 336.1205, R 335.1224, R 336.1702, R 336.2802, 40 CFR 52.21)

14. The permittee shall install, calibrate, maintain and oper ate in a satisfactory manner a device to monitor and record the TRS concentration in the vent gas to each flare in FGFLARES on a continuous basis. (R 336.1205, R 335.1224, R 336. 1702, R 336.2802, 40 CFR 52.21)

15. The permittee shall install, calibrate, maintain and operate in a satisfactory manner a gas chromatography system to monitor and record the total hydrocarbon, methane, and TRS concentration in the vent gas to

each flare in FGFLARES on a continuous basis. 3 (R 336.1201(3)) a. The gas chromatography system shall be maintained to be accurate within 5% of full scale. b. The minimum sampling frequency shall be one sample every 30 minutes.

See Appendices 1.3 and 1.4 of RO Permit 199700013c



### VII. REPORTING

1. The permittee shall provide written notification of construction and operation of EG-COKERFLARE to comply with the federal Standards of Performance for New Stationary Sources, 40 CFR 60.7. The permittee
shall submit this notification to the AQD District Supervisor within the time frames specified in

40 CFR 60.7. 2 (40 CFR 60.7)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 59 of 103

2. The permittee shall submit a copy of the Sulfur Shedding and Flare Minimization Plans to the AQD District Supervisor for review at least 60 days before commenc ing operation of equipment associated with the heavy oil upgrade project. 2 (R 336.1205, R 336.2802, 40 CFR 52.21, U.S. EPA Consent Order 01-40119)

3. The permittee shall submit to t he AQD District Supervisor an operati ons and maintenance (O&M) plan and a Flare Minimization Plan for each flare in FGFLARES at least 120 days before commencing operation of EG70-COKER. At a minimum the O&M plan shall in clude an inspection schedule and description of inspection procedures for the flare compone nts, including the flare tips and pilots. 2 (40 CFR Part 63 Subparts A & CC)

4. The permittee shall submit the dat a on the concentration of hydrogen sulfi de in the refinery fuel gas burned in the flares to the AQD District Supervisor in an ac ceptable format within 30 days following the end of the quarter in which the records were collected. 2 (40 CFR 60.105(a)(4))

5. The permittee shall submit a semiannual summary of reportable flaring incidents to the AQD District Supervisor. Each report shall include, as a mini mum, the number of reportabl e flaring incidents that occurred during the period, the amount of excess emissions during each reportable flaring incident, and the status of all yet-to-be-completed corrective actions fr om reportable flaring incidents. The permittee shall submit each report in an acceptable format within 30 days following the end of the semiannual period that the report covers. 2 (R 336.1205, R 336.2802, 40 CFR 52.21, U.S. EPA Consent Order 01-40119)

6. The permittee shall submit the information required by SC VI.8 to the AQD Permit Section Supervisor within 60 days following the end of each reporting year if bot h the following occur for any of these pollutants:

a. The calendar year actual emission from the Detr oit HOUP exceed the baseli ne actual emissions (BAE) by a significant amount, and

b. The calendar year actual emissions from the Detroi t HOUP differ from the pre-construction projection for

the emission units included in t he Hybrid Applicability Test used for the Detroit HOUP. The preconstruction projection is the sum of the projected actual emissions from each emission unit using the actual-to-projected actual emission s test as part of the Hybrid Applicability Test, and the potential

emissions from each emission unit usi ng the potential-to-emit test as part of t he Hybrid Applicability

Test.

The report shall contain the name, address, and te lephone number of the fa cility (major stationary source); the annual emissions as calculated pursuant to this SC, and any other information the owner or operator wishes to include (i.e., an explanation why emissions differ from the pre-construction projection). (R 336.2818, 40 CFR 52.21(r)(6)(v))

7. The permittee shall submit the information required by SC VI.8 to the AQD Permit Section Supervisor within 60 days following the end of each reporting year. The report shall contain the name, address, and telephone number of the facility (major stationary sour ce); the annual emissions as calculated pursuant to this SC, and any other information the owner or oper ator wishes to include (i.e., an explanation why emissions differ from the pre-construction projection). 3 (R 336.1201(3))



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. NA NA NA NAMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 60 of 103



### IX. OTHER REQUIREMENT(S)

1. NA

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).

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 61 of 103



### TABLE F-1.4 {FG-PROCVENTS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING This emission group includes miscellaneous process vents subject to Refinery MACT 1 (40 CFR Part 63, Subpart CC) Emission Unit/Process Groups EG06-VENTV34, EG07-VENTV12, EG11-VENT14SUMP, EG11- VENT21XF, EG11-VENT14XH, EG 11-VENT21V47, EG21-S2OFFGAS

I. DESIGN PARAMETERS A. Pollution Control Equipment Flare, FCCU Charge Heater

B. Stack/Vent Parameters Exhaust gases shall be discharged unobstr ucted vertically upwards unless

otherwise noted.

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp.

(°F) d.

Air Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA
C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutants Maximum Emission Limit

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. See Appendices 1.3 and 1.4 of RO Permit 199700013c

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. See Appendix 1.5 of RO Permit 199700013c

2. Method/Analysis 1. See Appendix 1.5 of RO Permit 199700013c 3. Frequency and Schedule of Testing/Recordkeeping 1. See Appendix 1.5 of RO Permit 199700013c

IV. REPORTING
Reports and Schedules See Appendix 1.8 of RO Permit 199700013c

V. OPERATIONAL PARAMETERS

NA

VI. OTHER REQUIREMENTS
1. Permittee shall comply with all applicable requireme nts of 40 CFR Part 63, National Emission Standards for

Hazardous Air Pollutants for Source Cat egories, Subpart A-General Provisions. (40 CFR Part 63, Subpart A)

2. Permittee shall comply with all applicable require ments of 40 CFR Part 63, Subpart CC-National Emission

Standards for Hazardous Air Pollutants from Petrol eum Refineries. See Appendix 1.7 of RO Permit

199700013c. (40 CFR Part 63, Subpart CC)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 62 of 103



### TABLE F-1.4 {FG-PROCVENTS}

FLEXIBLE GROUPING REQUIREMENTS

3. Permittee for a Group 1 miscellaneous process vent as defined in 40 CFR 63.641 shall comply with the requirements of either paragraphs (a) or (b) as follows: (40 CFR 63.643(a))

a. Permittee shall reduce emissions of organic H APs using a flare that meets the requirements of 40 CFR 63.11(b). Flares shall be operated at al l times when emissions may be vented to them. ( 40 CFR 63.643(a)(1)) b. Permittee shall reduce emissions of organic HA Ps, using a control device, by 98 percent or to a concentration of 20 parts per million by volume, on a dry basis, corrected to 3 percent oxygen, whichever is less stringent. Compliance can be determined by measuring either organic HAPs or TOCs using the procedures in 40 CFR 63.645. (40 CFR 63.643(a)(2))

4. If a boiler or process heater is used to comply with the percentage of reduction requirement or concentration limit specified in paragraph 40 CFR 63.643(a)(2), then the ve nt stream shall be introduced into the flame zone of such a device, or in a location such that the required percent reduction or concentration is achieved. Testing and monitoring is required only as specified in 40 CFR 63.644(a) and 63.645. (40 CFR 63.643(b))
* This requirement is state enforceable only.



### TABLE F-1.7 {FGGROUP2}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING Emission Unit/Process Groups EGTANK2, EGTANK9, EGTANK11, EGTANK16, EGTANK17, EGTANK18, EGTANK24, EGTANK27, EGTANK 28, EGTANK30, EGTANK31, EGTANK42, EGTANK43, EGTANK 50, EGTANK52, EGTANK54, EGTANK56, EGTANK59, EGTANK 60, EGTANK62, EGTANK63, EGTANK64, EGTANK66, EGTANK 70, EGTANK71, EGTANK100, EGTANK102, EGTANK103, EGTANK 105, EGTANK106, EGTANK107, EGTANK120, EGTANK125, EGTANK 126, EGTANK127, EGTANK128, EGTANK314, EGTANK315, EGTANK 316, EGTANK317, EGTANK318, EGTANK319, EGTANK320, EGTANK 324, EGTANK603, EGTANK608

I. DESIGN PARAMETERS

A. Pollution Control Equipment None

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d. Air

Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA
C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate
1. Sour kerosene 1. Throughput for FGGR OUP2 shall not exceed a monthly average of 8,400 barrels per day. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21) 2. Sweet kerosene 1. Throughput for FGGROU P2 shall not exceed a monthly average of 8,400 barrels per day. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21)

3. Sour distillates 1. Thro ughput for FGGROUP2 shall not exceed a monthly averageMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 63 of 103



### TABLE F-1.7 {FGGROUP2}

FLEXIBLE GROUPING REQUIREMENTS
of 44,400 barrels per day. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21)

4. Sweet distillates 1. Thro ughput for FGGROUP2 shall not exceed a monthly average of 44,400 barrels per day. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21) 5. Sour gasoil 1. Throughput for FGGROU P2 shall not exceed a monthly average of 46,800 barrels per day. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21) 6. Sweet gasoil 1. Throughput for FGGROU P2 shall not exceed a monthly average of 46,800 barrels per day. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21)

B. Pollutants Maximum Emission Limit

1. NA 1. NA

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. Permittee for each Group 1 or Group 2 storage vessel shall keep readily accessible records showing the dimensions of the storage vessel and an analysis showing the capacity of the storage vessel. This record shall be kept as long as the storage vessel retains Group 1 or Group 2 status and is in operation. (40 CFR 63.123(a)), (40 CFR 63.654(i))

2. For each material identified in II.A. above, the permittee shall keep monthly throughput records for FGGROUP2 . All records shall be kept on file for a period of at least five years and made available to the Department upon request. (R 336.1205, R 336.1702(a), R 336.2802, 40 CFR 52.21) 3. Other Monitoring and/or Recordkeeping 1. Recordkeeping as specified in Appendix 1.4 of RO Permit 199700013c

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. The permittee shall record the temperature of the stored product on a daily basis (alternative to true vapor pressure). (40 CFR 60.113) 2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. NA

IV. REPORTING
Reports and Schedules See Appendix 1.8 of RO Permit 199700013c

V. OPERATIONAL PARAMETERS

1. NA

VI. OTHER REQUIREMENTS
1. Permittee shall comply with all applicable requirem ents of 40 CFR 63, Subparts A, General and Subpart CC,

National Emission Standards for Hazardous Air Pollutants from Petroleum Refineries. (40 CFR 63.640)

2. Permittee shall identify each storage tank subject to 40 CFR 63, Subpart CC requirements. (40 CFR 63.654(f)(1)(i)(A))

3. Permittee shall comply with all applicable requirem ents of 40 CFR 63.640(l) for group 2 tanks that areMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 64 of 103



### TABLE F-1.7 {FGGROUP2}

FLEXIBLE GROUPING REQUIREMENTS
converted to Group 1 tanks. (40 CFR 63.640(l))

* This requirement is state enforceable only.



### TABLE F-1.8 {FG-IFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING Internal floating roof tanks (IFR) that are subject to 40 CFR Part 63, Subpart CC as Group 1 Vessels or subject to 40 CFR 60, Subpart Kb. These tanks also may be subject to Michigan Air Pollution Control Rule 604 (R 336.1604). This represents a consolidated requirement for internal floating roof tanks. Emission Unit/Process Groups EGTANK6, EGTANK8, EGTANK19, EGTANK23, EGTANK40, EGTANK45, EGTANK46, EGTANK47, EGTA NK48, EGTANK49 EGTANK51, EGTANK53, EGTANK55, EGTANK 57, EGTANK58, EGTANK61, EGTANK72, EGTANK79, EGTANK10 1, EGTANK104, EGTANK116, EGTANK120, EGTANK135, EGTANK 507, EGTANK508, EGTANK216

I. DESIGN PARAMETERS

A. Pollution Control Equipment Internal Floating Roof

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d. Air

Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutants Maximum Emission Limit
1. VOC 1. Vapor Pressure Maximum 11.0 psia (R 336.1225), (R 336.1702)

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. Recordkeeping as specified in Appendix 1.4 of RO Permit 199700013c

2. Permittee shall comply with t he applicable requirements of 40 CFR 60, Subpart Kb, section 60.116b (Monitoring of Operations) for EGTANK19, EGTANK23, EGTANK40, EGTANK49, EGTANK51, EGTANK53, EGTANK57, EGTANK79, EGTANK101, EGTANK104, EGTANK116, EGTANK120, EGTANK135, EGTANK508, and EGTANK216. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60, Subpart Kb, Section 60.116b)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 65 of 103



### TABLE F-1.8 {FG-IFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS
3. Permittee shall comply with t he applicable requirements of 40 CFR 60, Subpart Kb, section 60.116b (Monitor ing of Operations) for EGTANK6, EGTANK8, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK55, EGTANK58, EGTANK 61, EGTANK72, and EGTANK507. For purposes of this requirement, the term “applicable requirements of 40 CFR 60, Subpart Kb, section 60.116b (Monitoring of Operations)” refers to those requirements that would apply to these tanks if the tanks were actually subject to 40 CFR Part 60, Subpart Kb. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)
B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. Permittee shall comply with t he applicable requirements of 40 CFR 60, Subpart Kb, section 60.113b (Testi ng and Procedures), except as provided for in Refinery MACT 1, for EGTANK19, EGTANK23, EGTANK40, EGTANK49, EGTANK51, EGTANK53, EGTANK57, EGTANK79, EGTANK101, EGTANK104, EGTANK116, EGTANK120, EGTANK135, EGTANK508, and EGTANK216. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60, Subpart Kb, Section 60. 113b), (40 CFR 63, Subpart CC)

2. Permittee shall comply with the requirements of 40 CFR 60, Subpart Kb, section 60.113b (Testing and Procedures) that apply to tanks with internal floating roofs, except as provided for in Refinery MACT 1, for EGTANK6, EGTANK8, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK55, EGTANK58, EGTANK61, EGTANK72, and

EGTANK507. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21) 2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. NA

IV. REPORTING
Reports and Schedules See Appendix 1.8 of RO Permit 199700013c

V. OPERATIONAL PARAMETERS
Requirements V.1-V.3 apply to EGTANK19, EGTANK 23, EGTANK40, EGTANK49, EGTANK51, EGTANK53, EGTANK57, EGTANK79, EGTANK101, EGTANK104, EG TANK116, EGTANK120, EGTANK135, EGTANK508,

and EGTANK216.

1. Each opening in the internal floating roof except for leg sleeves, automatic bleeder vents, rim space vents, column wells, ladder wells, sample wells, and stub drai ns is to be equipped with a cover or lid which is to be maintained in a closed position at all times (i.e., no visibl e gap) except when the device is in actual use. The cover or lid shall be equipped with a gasket. Covers on each access hatch and automatic gauge float well shall be bolted except when they are in use. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.112b(a)(1)(iv))

2. Automatic bleeder vents shall be equipped with a gasket and are to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.112b(a)(1)(v))

3. The internal floating roof shall rest or float on the li quid surface (but not necessarily in complete contact with it) inside a storage vessel that has a fixed roof. The internal floating roof shall be floating on the liquid surface at all times, except during initial fill and durin g those intervals when the storage vessel is completely emptied or subsequently emptied and re filled. When the roof is resting on the leg supports, the process of filling, emptying, or refilling shall be continuous and shall be accomplished as rapidly as possible. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 3 36.2802), (40 CFR 52.21), ( 40 CFR 60.112b(a)(1)(i))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 66 of 103



### TABLE F-1.8 {FG-IFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

Requirements V.4-V.6 apply to EGTANK6, EGTANK 8, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK55, EGTANK58, EGTANK 61, EGTANK72, and EGTANK507.

4. Each opening in the internal floating roof except for leg sleeves, automatic bleeder vents, rim space vents, column wells, ladder wells, sample wells, and stub drai ns is to be equipped with a cover or lid which is to be maintained in a closed position at all times (i.e., no visibl e gap) except when the device is in actual use. The cover or lid shall be equipped with a gasket. Covers on each access hatch and automatic gauge float well shall be bolted except when they are in use. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

5. Automatic bleeder vents shall be equipped with a gasket and are to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

6. The internal floating roof shall rest or float on the li quid surface (but not necessarily in complete contact with it) inside a storage vessel that has a fixed roof. The internal floating roof shall be floating on the liquid surface at all times, except during initial fill and durin g those intervals when the storage vessel is completely emptied or subsequently emptied and re filled. When the roof is resting on the leg supports, the process of filling, emptying, or refilling shall be continuous and shall be accomplished as rapidly as possible. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

VI. OTHER REQUIREMENTS
Requirements VI.1-VI.14 apply to EGTANK19, EGTA NK23, EGTANK40, EGTANK49, EGTANK51, EGTANK53, EGTANK57, EGTANK79, EGTANK101, EGTANK104, EG TANK116, EGTANK120, EGTANK135, EGTANK508,

and EGTANK216.

1. Each internal floating roof shall be equipped with on e of the following closure devices between the wall of the storage vessel and the edge of the internal floating roof: a. A foam- or liquid-filled seal mount ed in contact with the liquid (liqui d-mounted seal). A liquid-mounted seal means a foam- or liquid-filled seal mounted in contact with the liquid between the wall of the storage vessel and the floating roof continuou sly around the circumference of the tank.

b. Two seals mounted one above the other so that each forms a continuous closure that completely covers the space between the wall of the storage vessel and the edge of the internal floating roof. The lower seal may be vapor-mounted, but both must be continuous.

c. A mechanical shoe seal. A mechanical shoe seal is a metal sheet held vertically against the wall of the storage vessel by springs or weighted levers and is connected by braces to the floating roof. A flexible coated fabric (envelope) spans the annular space between the metal sheet and the floating roof. (R 336.1205), R 336.1225), (R 336.1702( b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.112(b)(a)(1)(ii))

2. Each opening in a non-contact internal floating ro of except for automatic bleeder vents (vacuum breaker vents) and the rim space vents is to prov ide a projection below the liquid surface. (R 336.1205), (R 336.1225), (R 336.1 702(b)), (R 336.2802), (40 CFR 52.21 ), (40 CFR 60.112(b)(a)(1)(iii))

3. Rim space vents shall be equipped with a gasket and ar e to be set to open only when the internal floating roof is not floating or at the ma nufacturer's recommended setting. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.112(b)(a)(1)(vi))

4. Each penetration of the internal floating roof for the purpose of sampling shall be a sample well. The sample

well shall have a slit fabric cover that co vers at least 90 percent of the opening. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), ( 40 CFR 52.21), (40 CFR 60.112(b)(a)(1)(viii))

5. Each penetration of the internal floating roof that a llows for passage of a column supporting the fixed roofMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 67 of 103



### TABLE F-1.8 {FG-IFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

shall have a flexible fabric sleeve seal or a gasketed sliding cover. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.112(b)(a)(1)(viii))

6. Each penetration of the internal floating roof that allows for passage of a ladder shall have a gasketed sliding cover. (R 336.1205), (R 336.1225), (R 336.1 702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.112(b)(a)(1)(ix))

7. Visually inspect the internal floating roof, the primar y seal, and the secondary seal (if one is in service), prior to filling the storage vessel with VOL. If there are holes, tears, or other openings in the primary seal, the secondary seal, or the seal fabric or defects in the internal floating roo f, or both, the owner or operator shall repair the items before filling the storage vessel. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CF R 52.21), (40 CFR 60.113(b)(a)(1))

8. For Vessels equipped with a liquid-mounted or mechanical shoe primary seal, visually inspect the internal floating roof and the primary seal or the secondary s eal (if one is in service) through manholes and roof

hatches on the fixed roof at least once every 12 months after initial fill. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CF R 52.21), (40 CFR 60.113(b)(a)(2))

9. If the internal floating roof is not resting on the su rface of the VOL inside the storage vessel, or there is liquid accumulated on the roof, or the seal is detached, or there are holes or tears in the seal fabric, the owner or operator shall repair the items or empty a nd remove the storage vessel from service within 45 days. If a failure that is detected during inspections r equired in this paragraph cannot be repaired within 45 days and if the vessel cannot be emptied within 45 day s, a 30-day extension may be requested from the Administrator in the inspection report required in Se c. 60.115b(a)(3). Such a request for an extension

must document that alternate st orage capacity is unavailable and specify a schedule of actions the company will take that will assure that the control eq uipment will be repaired or the vessel will be emptied as soon as possible. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.113(b)(a)(3))

10. For vessels equipped with a double- seal system, permittee must visually inspect the internal floating roof, the primary seal, the secondary seal (if one is in serv ice), gaskets, slotted membranes and sleeve seals (if any) each time the storage vessel is emptied and degassed, or at least every five y ears; or visually inspect the IFR and the primary and secondary seal through t he manhole and roof hatches at least once every 12

months after initial fill. (R 336.1205), (R 336.1225), (R 336.1 702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.113(b)(a)(2))

11. Visually inspect the internal floating roof, the primar y seal, the secondary seal (if one is in service), gaskets, slotted membranes and sleeve seals (if any) each time the storage vessel is emptied and degassed. If the internal floating roof has defects, the primary seal has ho les, tears, or other openings in the seal or the seal fabric, or the secondary seal has holes, tears, or other openings in the seal or the seal fabric, or the gaskets no longer close off the liquid surfaces from the at mosphere, or the slotted membrane has more than 10 percent open area, the owner or operator shall repair t he items as necessary so t hat none of the conditions specified in this paragraph exist before refilling the st orage vessel with VOL. In no event shall inspections conducted in accordance with this provision occur at intervals greater than 10 years in the case of vessels conducting the annual visual inspection as specified in paragraphs40 CFR 60.113b(a)(2) and (a)(3)(ii) and at intervals no greater than five years in the case of vessels specified in paragraph 40 CFR 60.113b (a)(3)(i). (R 336.1205), (R 336.1225), (R 336.1702(b )), (R 336.2802), (40 CFR 52.21), (40 CFR 60.113(b)(a)(4))

12. Notify the Administrator in writing at least 30 days prior to the filling or refilling of each storage vessel for which an inspection is required by paragraphs (a)(1) an d (a)(4) of this section to afford the Administrator the opportunity to have an observer present. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 336.2802), (40 CFR 52.21), (40 CFR 60.113(b)(a)(5))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 68 of 103



### TABLE F-1.8 {FG-IFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

13. If the inspection required by paragraph 40 CFR 60. 113b(a)(4) is not planned and the owner or operator could not have known about the inspection 30 days in adv ance or refilling the tank , the owner or operator shall notify the Administrator at least seven days prior to the refilling of t he storage vessel. Notification shall be made by telephone immediately followed by written documentation demonstrating why the inspection was unplanned. Alternatively, this notification including the written documentation may be made in writing and sent by express mail so that it is received by the Administrator at least seven days prior to the refilling. (R 336.1205), (R 336.1225), (R 336.1702(b)), (R 3 36.2802), (40 CFR 52.21), (40 CFR 60.113(b)(a)(5))

14. The permittee shall comply with all applicable provisions of 40 CFR 60, Subparts A and Kb. (40 CFR 60, Subparts A and Kb)

Requirements VI.15-V.27 apply to EGTANK6, EGTANK 8, EGTANK45, EGTANK46, EGTANK47, EGTANK48, EGTANK55, EGTANK58, EGTANK 61, EGTANK72, and EGTANK507.

15. Each internal floating roof shall be equipped with on e of the following closure devices between the wall of the storage vessel and the edge of the internal floating roof: a. A foam- or liquid-filled seal mount ed in contact with the liquid (liqui d-mounted seal). A liquid-mounted seal means a foam- or liquid-filled seal mounted in contact with the liquid between the wall of the storage vessel and the floating roof continuou sly around the circumference of the tank.

b. Two seals mounted one above the other so that each forms a continuous closure that completely covers the space between the wall of the storage vessel and the edge of the internal floating roof. The lower seal may be vapor-mounted, but both must be continuous.

c. A mechanical shoe seal. A mechanical shoe seal is a metal sheet held vertically against the wall of the storage vessel by springs or weighted levers and is co nnected by braces to the floating roof. A flexible coated fabric (envelope) spans the annular spac e between the metal sheet and the floating roof. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

16. Each opening in a non-contact internal floating ro of except for automatic bleeder vents (vacuum breaker vents) and the rim space vents is to prov ide a projection below the liquid surface. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

17. Rim space vents shall be equipped with a gasket and ar e to be set to open only when the internal floating roof is not floating or at the ma nufacturer's recommended setting. R 336.1205), ((R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

18. Each penetration of the internal floating roof for the purpose of sampling shall be a sample well. The sample

well shall have a slit fabric cover that co vers at least 90 percent of the opening. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

19. Each penetration of the internal floating roof that a llows for passage of a column supporting the fixed roof

shall have a flexible fabric sleeve seal or a gasketed sliding cover. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

20. Each penetration of the internal floating roof that allows for passage of a ladder shall have a gasketed sliding cover. (R 336.1205), (R 336.1225), (R 336. 1702(a)), (R 336.2802), (40 CFR 52.21)

21. Visually inspect the internal floating roof, the primary seal, and the secondary seal (if one is in service), prior to filling the storage vessel with VOL. If there are hole s, tears, or other openings in the primary seal, the secondary seal, or the seal fabric or defects in the in ternal floating roof, or both, the owner or operator shall repair the items before filling the storage vessel. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

22. For Vessels equipped with a liquid-mounted or mechanical shoe primary seal, visually inspect the internal floating roof and the primary seal or the secondary s eal (if one is in service) through manholes and roofMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 69 of 103



### TABLE F-1.8 {FG-IFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

hatches on the fixed roof at least once every 12 months after initial fill. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

23. If the internal floating roof is not resting on the su rface of the VOL inside the storage vessel, or there is liquid accumulated on the roof, or the seal is detached, or there are holes or tears in the seal fabric, the owner or operator shall repair the items or empty a nd remove the storage vessel from service within 45 days. If a failure that is detected during inspections r equired in this paragraph cannot be repaired within 45 days and if the vessel cannot be emptied within 45 day s, a 30-day extension may be requested from the Administrator in the inspection report required in Sec. 60.115b(a)(3). Such a request for an extension must document that alternate storage capacity is unavailabl e and specify a schedule of actions the company will take that will assure that the control equipment will be repaired or the vessel will be emptied as soon as possible. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

24. For vessels equipped with a double- seal system, permittee must visually inspect the internal floating roof, the primary seal, the secondary seal (if one is in serv ice), gaskets, slotted membranes and sleeve seals (if any) each time the storage vessel is emptied and degassed, or at least every five y ears; or visually inspect the IFR and the primary and secondary seal through t he manhole and roof hatches at least once every 12

months after initial fill. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

25. Visually inspect the internal floating roof, the primar y seal, the secondary seal (if one is in service), gaskets, slotted membranes and sleeve seals (if any) each time the storage vessel is emptied and degassed. If the internal floating roof has defects, the primary seal has ho les, tears, or other openings in the seal or the seal fabric, or the secondary seal has holes, tears, or other openings in the seal or the seal fabric, or the gaskets no longer close off the liquid surfaces from the at mosphere, or the slotted membrane has more than 10 percent open area, the owner or operator shall repair t he items as necessary so t hat none of the conditions specified in this paragraph exist before refilling the st orage vessel with VOL. In no event shall inspections conducted in accordance with this provision occur at intervals greater than 10 years in the case of vessels conducting the annual visual inspection as specifi ed in paragraphs40 CFR 60.113b( a)(2) and (a)(3)(ii) and at intervals no greater than five years in the case of vessels specified in paragraph 40 CFR 60.113b (a)(3)(i). (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

26. Notify the Administrator in writing at least 30 days prior to the filling or refilling of each storage vessel for which an inspection is required by paragraphs (a)(1) and (a )(4) of this section to afford the Administrator the opportunity to have an observer present. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

27. If the inspection required by paragraph 40 CFR 60. 113b(a)(4) is not planned and the owner or operator could not have known about the inspection 30 days in adv ance or refilling the tank , the owner or operator shall notify the Administrator at least seven days prior to the refilling of t he storage vessel. Notification shall be made by telephone immediately followed by written documentation demonstrating why the inspection was unplanned. Alternatively, this notification including the written documentation may be made in writing and sent by express mail so that it is received by the Administrator at least seven days prior to the refilling. (R 336.1205), (R 336.1225), (R 336.1702(a)), (R 336.2802), (40 CFR 52.21)

The following requirements apply to all tanks in FG-IFRTANKS.

28. The permittee shall comply with all applicable provisions of Rule 604. (R 336.1604)

29. The permittee may utilize the provisions of 40 CF R 63, Subpart CC, Section 63.640(n) for storage vessels included in FG-IFRTANKS (Overlap of subpart CC with other regulations for storage vessels). (40 CFR 63, Subpart CC, Section 63.640(n))
* This requirement is state enforceable only.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 70 of 103



### TABLE F-1.9 {FG-EFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING This flexible group represents a co nsolidated requirement for external floating roof (EFR) tanks t hat are subject to 40 CFR Part 63, Subpart CC as Group 1 Vessels or subject to 40 CFR 60, Subpart Kb. These tanks may also be subject to Michigan Air Pollution Control Rule 623 (R 336.1623) and/or NSPS Subpart QQQ. This cons olidated requirement basically adopts NSPS Kb for these EFR tanks. Emission Unit/Process Groups EGTANK32, EGTANK33, EGTANK10 8, EGTANK109, EGTANK110, EGTANK112, EGTANK113, EGTANK 114, EGTANK115, EGTANK128, EGTANK129, EGTANK130, EGTANK601

I. DESIGN PARAMETERS

A. Pollution Control Equipment External Floating Roof

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d. Air

Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA
C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutants Maximum Emission Limit

1. NA 1. NA

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. Recordkeeping as specified in Appendix 1.4 of RO Permit 199700013c.

2. Permittee shall comply with the applicable requirements of 40 CFR 60, Subpart Kb, section 60.116b (Monitoring of Operations) for

EGTANK129. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60, Subpart Kb, Section 60.116b)

3. Permittee shall comply with the requirements of 40 CFR 60, Subpart Kb, section 60.116b (Monitoring of Operations) that apply to tanks with external floating roofs, for EGTANK32, EGTANK33, EGTANK108, EGTANK109, EGTANK110, EGTANK 112, EGTANK113, EGTANK114, EGTANK115, EGTANK130, and EGTANK601. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21)

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. Permittee shall comply with the applicable requirements of 40 CFR 60, Subpart Kb, section 60.113b (Testi ng and Procedures), except asMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 71 of 103



### TABLE F-1.9 {FG-EFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

provided for in Refinery MACT 1, for EGTANK129. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.28 02, 40 CFR 52.21, 40 CFR 60, Subpart Kb, Section 60.113b, 40 CFR 63, Subpart CC)

2. Permittee shall comply with the applicable requirements of 40 CFR 60, Subpart Kb, section 60.113b (Testi ng and Procedures), except as provided for in Refinery MACT 1, for EGTANK32, EGTANK33, EGTANK108, EGTANK109, EGTANK 110, EGTANK112, EGTANK113, EGTANK114, EGTANK115, EGTANK130, and EGTANK601. For purposes of this requirement, the term “applicable requirements of 40 CFR 60, Subpart Kb, section 60.113b (Testing and Procedures), except as provided for in Refi nery MACT 1” refers to those requirements that would apply to thes e tanks if the tanks were actually subject to 40 CFR Part 60, Subpart Kb. (R 336.1205, R 336.1225*, R 336.1702(a), R 338.2802, 40 CFR 52.21) 2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. NA

IV. REPORTING
Reports and Schedules

V. OPERATIONAL PARAMETERS
Requirements V.1-V.4 apply to EGTANK129.

1. Each external floating roof shall be equipped with a closure device between the wa ll of the storage vessel and the roof edge. The closure device is to consist of two seals, one above the other. The lower seal is referred to as the primary seal, and the upper seal is referred to as the secondary seal. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.112b(a)(2)(i))

2. The primary seal shall be either a mechanical shoe se al or a liquid-mounted seal. Except as provided in 40 CFR 60.113b(b)(4), the s eal shall completely cover the annular space between the edge of the floating roof and tank wall. The secondary seal shall comp letely cover the annular space between the external floating roof and the wall of the storage vessel in a continuous fashion except as allowed in 40 CFR 60.113(b)(4) (45-day repair require ment + 30-day extension). (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.112b(a)(2)(i)(A) and (B))

3. Except for automatic bleeder vent s and rim space vents, each opening in a noncontact external floating roof shall provide a projection below the liquid surface. Exc ept for automatic bleeder vents, rim space vents, roof drains, and leg sleeves, each opening in the roof is to be equipped with a gasket cover, seal, or lid that is to be maintained in a closed position at all times (i.e., no visible gap) except when the device is in actual use.

Automatic bleeder vents are to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports. Rim vents are to be set to open when the roof is being floated off the roof legs supports or at the manufac turer's recommended setting. Automatic bleeder vents and rim space vents are to be gasketed. Each emerge ncy roof drain is to be provided with a slotted

membrane fabric cover that covers at leas t 90 percent of the area of the opening. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52 .21, 40 CFR 60.112b(a)(2)(ii))

4. The roof shall be floating on the liquid at all times (i.e., off the roof leg supports) except during initial fill until the roof is lifted off leg supports and when the tank is completely emptied and subsequently refilled. The process of filling, emptying, or refilling when the roof is resting on the leg supports shall be continuous and shall be accomplished as rapidly as possible. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.112b(a)(2)(iii))

Requirements V.5-V.8 apply to EGTANK32, EG TANK33, EGTANK108, EGTANK109, EGTANK110, EGTANK112, EGTANK113, EGTANK114, EGTANK115, EGTANK130, and EGTANK601Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 72 of 103



### TABLE F-1.9 {FG-EFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

5. Each external floating roof shall be equipped with a closure device between the wa ll of the storage vessel and the roof edge. The closure device is to consist of two seals, one above the other. The lower seal is referred to as the primary seal, and the upper seal is referred to as the secondary seal. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21)

6. The primary seal shall be either a mechanical shoe se al or a liquid-mounted seal. Except as provided in 40 CFR 60.113b(b)(4), the s eal shall completely cover the annular space between the edge of the floating roof and tank wall. The secondary seal shall comp letely cover the annular space between the external floating roof and the wall of the storage vessel in a continuous fashion except as allowed in 40 CFR 60.113(b)(4) (45-day repair r equirement + 30-day extension). (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21)

7. Except for automatic bleeder vent s and rim space vents, each opening in a noncontact external floating roof shall provide a projection below the liquid surface. Exc ept for automatic bleeder vents, rim space vents, roof drains, and leg sleeves, each opening in the roof is to be equipped with a gasket cover, seal, or lid that is to be maintained in a closed position at all times (i.e., no visible gap) except when the device is in actual use.

Automatic bleeder vents are to be closed at all times when the roof is floating except when the roof is being floated off or is being landed on the roof leg supports. Rim vents are to be set to open when the roof is being floated off the roof legs supports or at the manufac turer's recommended setting. Automatic bleeder vents and rim space vents are to be gasketed. Each emergenc y roof drain is to be provided with a slotted

membrane fabric cover that covers at leas t 90 percent of the area of the opening. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21)

8. The roof shall be floating on the liquid at all times (i.e., off the roof leg supports) except during initial fill until the roof is lifted off leg supports and when the tank is completely emptied and subsequently refilled. The process of filling, emptying, or refilling when the roof is resting on the leg supports shall be continuous and shall be accomplished as rapidly as possible. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21)

VI. OTHER REQUIREMENTS
Requirements VI.1-VI.9 apply to EGTANK129.

1. Permittee shall determine the gap areas and maximum gap widths, between the primary seal and the wall of the storage vessel and between the secondary seal and the wall of the storage vessel according to the following frequency: (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(1))

i. Measurements of gaps between the tank wall and t he primary seal (seal gaps) shall be performed during the hydrostatic testing of the vessel or within 60 days of the initial fill with VOL and at least once every five years thereafter. (R 336.1205, R 336.1225*, R 336.1 702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(1)(i)) ii. Measurements of gaps between the tank wall and the secondary seal shall be performed within 60 days of the initial fill with VOL and at least once per year thereafter. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52 .21, 40 CFR 60.113b(b)(1)(ii)) iii. If any source ceases to store VOL for a period of 1 year or more, subsequent introduction of

VOL into the vessel shall be considered an init ial fill for the purposes of paragraphs 40 CFR 60.113b(b)(1)(i) and (b)(1)(ii). (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(1)(iii))

2. Permittee shall determine gap widths and areas in the primary and secondary seals individually by the following procedures: (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(2))

i. Measure seal gaps, if any, at one or more floating roof levels when the roof is floating off the roof leg supports. (R 336.1205, R 336.1225*, R 336.1702 (b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(2)(i))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 73 of 103



### TABLE F-1.9 {FG-EFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

ii. Measure seal gaps around the ent ire circumference of the tank in each place where a 0.32-cm diameter uniform probe passes fr eely (without forcing or binding agai nst the seal) between the seal and the wall of storage vessel and measure the circ umferential distance of each such location. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.28 02, 40 CFR 52.21, 40 CFR 60.113b(b)(2)(ii)) iii. The total surface area of each gap described in pa ragraph (b)(2)(ii) of this section shall be determined by using probes of various widths to measure accu rately the actual distance from the tank wall to the seal and multiplying each such width by its respective circumferential distance. (R 336.1205, R 336.1225*, R 336.1702 (b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(2)(iii))

3. Permittee shall add the gap surface area of each gap location for the primary seal and the secondary seal individually and divide the sum for each seal by the nomi nal diameter of the tank and compare each ratio to the respective standards in par agraph 40 CFR 60.113b(b)(4). (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(3))

4. Permittee shall make necessary repairs or empty the storage vessel within 45 days of identification in any inspection for seals not meeting the following requirements (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)) : i. The accumulated area of gaps between the tank wall and the mechanical shoe or liquid-mounted primary seal shall not exceed 212 Cm(2) per meter of tank diameter, and the width of any portion of any gap shall not exceed 3.81 cm. (A) One end of the mechanical shoe is to extend into the stored liquid, and the other end is to extend a minimum ve rtical distance of 61 cm above the stored liquid surface. (B) There are to be no holes, tears, or other openings in the shoe, seal fabric, or seal envelope. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)(i)) ii. The secondary seal is to meet the following require ments: (A) The secondary seal is to be installed above the primary seal so that it completely cove rs the space between the roof edge and the tank wall except as provided in paragraph 40 CFR 60.113b(b) (2)(iii). (B) The accumulated area of gaps between the tank wall and the secondary seal shall not exceed 21.2 cm(2) per meter of tank diameter, and the width of any portion of any gap shall not exceed 1.27 cm. (C) There are to be no holes, tears, or other openings in the secondary seal or seal fabric. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)(ii)) iii. If a failure that is detected during inspection s required in paragraph 40 CFR 60.113b(b)(1) cannot be repaired within 45 days and if the vessel cannot be emptied within 45 days, a 30-day extension may be requested from the Administrator in the inspection report required in 40 CFR 60.115(b)(4). Such extension request must include a demonstration of unavailability of alternate storage capacity and a specification of a schedule that will assure that t he control equipment will be repaired or the vessel will be emptied as soon as possible. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)(iii))

5. Permittee shall notify the Administrator 30 day s in advance of any gap measurements required by paragraph 40 CFR 60.113b(b)(1) to afford the Admini strator the opportunity to have an observer present. (R 336.1205, R 336.1225*, R 336.1702(b), R 336. 2802, 40 CFR 52.21, 40 CFR 60.113b(b)(5))

6. Permittee shall visually inspect the external floatin g roof, the primary seal, secondary seal, and fittings each time the vessel is emptied and degassed. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(6))

7. If the external floating roof has hole s, tears, or other openings in the seal or the seal fabric, or the secondary seal has holes, tears, or other openings in the seal or the seal fabric, the permittee shall repair the items as necessary so that none of the conditions specified in this para graph exist before filling or refilling the storage vessel with VOL. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(6)(i))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 74 of 103



### TABLE F-1.9 {FG-EFRTANKS}

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8. For all the inspections requir ed by paragraph 40 CFR 60.113b(b)(6 ), the permittee shall notify the Administrator in writing at least 30 days prior to the f illing or refilling of each storage vessel to afford the Administrator the opportunity to inspect the storage vess el prior to refilling. If the inspection required by paragraph 40 CFR 60.113b(b)(6) is not planned and the permittee could not have known about the inspection 30 days in advance of re filling the tank, the permittee shall notif y the Administrator at least seven days prior to the refilling of the storage vessel. Notification shall be made by telephone immediately followed by written documentation demonstrating why the inspection was unplanned. Alternatively, this notification including the written documentation may be m ade in writing and sent by ex press mail so that it is received by the Administrator at leas t seven days prior to the refilling. (R 336.1205, R 336.1225*, R 336.1702(b), R 336.2802, 40 CFR 52 .21, 40 CFR 60.113b(b)(6)(ii))

9. The permittee shall comply with all appl icable provisions of 40 CFR 60 as follows: Subpart A- General Subpart Kb- Standards of Perfor mance for Volatile Organic Liquid Storage Vessels (40 CFR 60, Subparts A and Kb)

Requirements VI.10-VI.17 apply to EGTANK32, EGTANK33, EGTANK108, EGTANK109, EGTANK110, EGTANK112, EGTANK113, EGTANK114, EGTANK115, EGTANK130, and EGTANK601.

10. Permittee shall determine the gap areas and maximum gap widths, between the primary seal and the wall of the storage vessel and between the secondary seal and the wall of the storage vessel according to the following frequency: (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(1))

i. Measurements of gaps between the tank wall and t he primary seal (seal gaps) shall be performed during the hydrostatic testing of the vessel or within 60 days of the initial fill with VOL and at least once every five years thereafter. (R 336.1205, R 336.1225*, R 336. 1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(1)(i)) ii. Measurements of gaps between the tank wall and the secondary seal shall be performed within 60 days of the initial fill with VOL and at least once per year thereafter. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52 .21, 40 CFR 60.113b(b)(1)(ii)) iii. If any source ceases to store VOL for a peri od of one year or more, subsequent introduction of

VOL into the vessel shall be considered an initial fill for the purposes of paragraphs 40 CFR 60.113b(b)(1)(i) and (b)(1)(ii). (R 336.1205, R 336.1225*, R 336.1702 (a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(1)(iii))

11. Permittee shall determine gap widths and areas in the primary and secondary seals individually by the following procedures: (R 336.1205, R 336.1225*, R 336.1702 (a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(2))

i. Measure seal gaps, if any, at one or more floating roof levels when the roof is floating off the roof leg supports. (R 336.1205, R 336.1225*, R 336.1702 (a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(2)(i)) ii. Measure seal gaps around the ent ire circumference of the tank in each place where a 0.32-cm diameter uniform probe passes fr eely (without forcing or binding agai nst the seal) between the seal and the wall of storage vessel and measure the circ umferential distance of each such location. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.28 02, 40 CFR 52.21, 40 CFR 60.113b(b)(2)(ii)) iii. The total surface area of each gap described in pa ragraph (b)(2)(ii) of this section shall be determined by using probes of various widths to measure accura tely the actual distance from the tank wall to the seal and multiplying each such width by its respective circumferential distance. (R 336.1205, R 336.1225*, R 336.1702 (a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(2)(iii))

12. Permittee shall add the gap surface area of each gap location for the primary seal and the secondary seal individually and divide the sum for each seal by the nomi nal diameter of the tank and compare each ratio to the respective standards in pa ragraph 40 CFR 60.113b(b)(4). (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(3))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 75 of 103



### TABLE F-1.9 {FG-EFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

13. Permittee shall make necessary repairs or empty the storage vessel within 45 days of identification in any inspection for seals not meeting the following requirements (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, (40 CFR 52.21, 40 CFR 60.113b(b)(4)) : i. The accumulated area of gaps between the tank wall and the mechanical shoe or liquid-mounted primary seal shall not exceed 212 Cm(2) per meter of tank diameter, and the width of any portion of any gap shall not exceed 3.81 cm. (A) One end of the mechanical shoe is to extend into the stored liquid, and the other end is to extend a minimum ve rtical distance of 61 cm above the stored liquid surface. (B) There are to be no hol es, tears, or other openings in the shoe, seal fabric, or seal envelope. (R 336.1205, R 336.1225*, R 336.1702( a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)(i)) ii. The secondary seal is to meet the following require ments: (A) The secondary seal is to be installed above the primary seal so that it completely cove rs the space between the roof edge and the tank wall except as provided in paragraph 40 CFR 60.113b(b) (2)(iii). (B) The accumulated area of gaps between the tank wall and the secondary seal shall not exceed 21.2 cm(2) per meter of tank diameter, and the width of any portion of any gap shall not exceed 1.27 cm. (C) There are to be no holes, tears, or other openings in the secondary seal or seal fabric. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)(ii)) iii. If a failure that is detected during inspection s required in paragraph 40 CFR 60.113b(b)(1) cannot be repaired within 45 days and if the vessel cannot be emptied within 45 days, a 30-day extension may be requested from the Administrator in the inspection report required in 40 CFR 60.115(b)(4). Such extension request must include a demonstration of unavailability of alternate storage capacity and a specification of a schedule that will assure that t he control equipment will be repaired or the vessel will be emptied as soon as possible. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(4)(iii)

14. Permittee shall notify the Administrator 30 day s in advance of any gap measurements required by paragraph 40 CFR 60.113b(b)(1) to afford the Admini strator the opportunity to have an observer present. (R 336.1205, R 336.1225*, R 336.1702(a), R 336. 2802, 40 CFR 52.21, 40 CFR 60.113b(b)(5)) 15. Permittee shall visually inspect the external floatin g roof, the primary seal, secondary seal, and fittings each time the vessel is emptied and degassed. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(6))

16. If the external floating roof has holes, tears, or other openings in t he seal or the seal fabric, or the secondary seal has holes, tears, or other openings in t he seal or the seal fabric, the permittee shall repair the items as necessary so that none of the conditions specified in this paragraph exist before filling or refilling the storage vessel with VOL. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(6)(i))

17. For all the inspections requir ed by paragraph 40 CFR 60.113b(b)(6 ), the permittee shall notify the Administrator in writing at least 30 days prior to the f illing or refilling of each storage vessel to afford the Administrator the opportunity to inspect the storage vess el prior to refilling. If the inspection required by paragraph 40 CFR 60.113b(b)(6) is not planned and the permittee could not have known about the inspection 30 days in advance of re filling the tank, the permittee shall notif y the Administrator at least seven days prior to the refilling of the st orage vessel. Notification shall be made by telephone immediately followed by written documentation demonstrating why the inspec tion was unplanned. Alternatively, this notification including the written documentation may be made in writi ng and sent by express mail so that it is received by the Administrator at least se ven days prior to the refilling. (R 336.1205, R 336.1225*, R 336.1702(a), R 336.2802, 40 CFR 52.21, 40 CFR 60.113b(b)(6)(ii))

The following requirements apply to all tanks in FG-EFRTANKS.

18. The permittee shall comply with all applicable provisions of Rule 623. (R 336.1623)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 76 of 103



### TABLE F-1.9 {FG-EFRTANKS}

FLEXIBLE GROUPING REQUIREMENTS

19. The permittee may utilize the provisions of 40 CF R 63, Subpart CC, Section 63.640(n) for storage vessels included in FG-EFRTANKS (Overlap of subpart CC with other regulations for storage vessels). (40 CFR 63, Subpart CC, Section 63.640(n))

20. The permittee shall document it’s current storage tank inspection and ma intenance protocol. The protocol shall include provisions to increase inspection freque ncy on the storage tanks during winter months and to winterize the storage tank roof drains seasonally. 3 (R 336.1201(3))
* This requirement is state enforceable only.

3 This condition is included at the request of the permittee.



### TABLE F-1.12 {FG29-IGF}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING Flexible grouping consisting of two induced gas flotation units which are part of the wastewater treatment plant and are covered by permit 190-00A. Emission Unit/Process Groups EG29-IGF1, EG29-IGF2 Flexible Grouping ID FGDHOUPANNUAL

I. DESIGN PARAMETERS A. Pollution Control Equipment None

B. Stack/Vent Parameters Exhaust gases shall be discharged unobs tructed vertically upwards unless

otherwise noted.

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d.

Air Flow

Rate (acfm) Applicable Requirement

1. SV29-IGF1 20 * 6 * NA NA R 336.1225

2. SV29-IGF2 20 * 6 * NA NA R 336.1225
C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutants Maximum Emission Limit
1.Volatile Organic Compounds 1. 8.41 tons per 12-month rolling time period (R 336.1702(a)), (R 336.1225)

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. The permittee shall monitor the pr essure setting on each decant vessel

conservation vent in a manner and wi th instrumentation acceptable to

the Division. (R 336.1225), (R 336.1702(a)), (R 336.1910)

2. Permittee shall continuously monitor the wastewater throughput for FG29-IGF in a manner and with instrumentation acceptable to the

Division . (R 336.1225), (R 336.1702(a)), (R 336.1910)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 77 of 103



### TABLE F-1.12 {FG29-IGF}

FLEXIBLE GROUPING REQUIREMENTS 3. Other Monitoring and/or Recordkeeping 1. Permittee shall maintain the following written records for FG29-IGF:

a. A record of monthly wastewater throughputs as determined at the

end of each calendar month. b. A record of monthly VOC emission rate including the 12-month rolling time period emission rate. c. A record demonstrating the calculations used to determine the
VOC emission rate. d. Once every eight-hour shift, the permittee shall record the pressure setting for each decant vessel conservation vent. e. Once every eight-hour shift, the permittee shall record the position

of each decant vessel conservation vent valve.

The above written records shall be maintained for a period of at least five years and shall be made available to the Division upon request. (R 336.1225), (R 336.1702(a)), (R 336.1910)

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. NA

2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. NA

IV. REPORTING
Reports and Schedules

V. OPERATIONAL PARAMETERS
1. The wastewater throughput for FG29-IGF shall not exceed 1,682,000,000 gallons per 12-month rolling time period as determined at the end of each calendar month. (R 336.1225), (R 336.1702(a))

2. Permittee shall ensure FG29-IGF meets all the a pplicable standards of the Federal National Emission Standards for Hazardous Air Pollutants, 40 CFR, Part 61, Subparts A and FF. (R 336.1213(3))

3. Permittee shall ensure FG29-IGF meets all the a pplicable standards of the Federal National Emission

Standards for Hazardous Air Pollutants for Source Ca tegories, 40 CFR, Part 63, Subparts A and CC at existing sources. (R 336.1213(3))

4. Permittee shall not operate EG29-IGF1 or EG29-IGF 2 unless the fixed roofs and conservation vent for the emission unit are installed and operating properly. (R 336.1225), (R 336.1702(a)), (R 336.1910)

5. The pressure setting on decant vessel conservation vent s in FG29-IGF shall be equal to or greater than 2.0 pounds per square inch gauge. (R 336.1225), (R 336.1702(a)

, (R 336.1910)

VI. OTHER REQUIREMENTS

1. NA
* This requirement is state enforceable only.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 78 of 103



### TABLE F-1.11 {FG-PROCUNITS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING Process groups subject to leak detect ion and repair requirements (LDAR). This flexible grouping is subject to the consolidated LDAR requirements of 40 CFR 60, Subparts VV and VVa; 40 CFR 60, Subparts GGG and GGGa; 40 CFR 63, Subpart CC as listed in Section VI of this table. For the purpose of this consolidated LDAR requirement the following are affected facilities: (1) compressors and (2) the group of all equipment {see definition in 40 CFR 60.591} within a process unit.

Emission Unit/Process Groups EG04VACUUM, EG05-CRUDE, EG07-DHT, EG08-GOHT, EG09-ALKYLATION, EG11-FCCU, EG12-GASCON, EG13-PROPYLENE, EG14-CCRPLATFORMER, EG16-NAP HHYTREAT, EG19-KEROHYTREAT, EG21-CPTREATER, EG22-TANKFA RMS, EG22-LPGRAILRACK, EG29-WASTEWATER, EG38-ROUGET ERMNL, EG42-43SULRECOV, EG99-LPGLOADRACK, EG41-S OURWATER, EG22-ASPHLOAD, EG70-COKERPLANT, EG71-H2PL ANT, EG72-SULRBLOCK2, EG73-SOURWATER2, EG77-DHTH YTREAT, EG76-UTILITIES,

EG78-FUELGASRECOVERY Flexible Grouping ID FGDHOUPANNUAL

I. DESIGN PARAMETERS A. Pollution Control Equipment NA

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum
Exhaust Dimension (inches) c. Temp

(F) d. Air

Flow Rate

(acfm) Applicable Requirement

NA NA NA NA NA NA C. Other Design Parameters

1.

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutants Maximum Emission Limit 1. VOC For all pumps: A leak shall be defined as an instrument reading of 2,000 ppm or greater, as specified in NSPS Subpart VVa. (Consent Order No. 01-40119, 40 CFR Part 60 Subpart GGGa)

For valves in gas/vapor or light liquid service: A leak shall be defined as an instrument reading of 500 ppm or greater, as specified in NSPS Subpart VVa. (Consent Order No. 01-40119, 40 CFR Part 60 Subpart GGGa)

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. See Appendix 1.4 of RO Permit 199700013cMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 79 of 103



### TABLE F-1.11 {FG-PROCUNITS}

FLEXIBLE GROUPING REQUIREMENTS

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded NA

2. Method/Analysis NA

3. Frequency and Schedule of Testing/Recordkeeping NA

IV. REPORTING
Reports and Schedules See Appendix 1.8 of RO Permit 199700013c

V. OPERATIONAL PARAMETERS

NA

VI. OTHER REQUIREMENTS

1. Permittee shall not cause or allow the emission of any volatile organic compound from any existing component, as listed in R 336.1622(2), of a petroleum refinery, includi ng topping plants, unless all applicable provisions of 40 CFR 60.590 to 60.593 (2000), standards of performance for equipment leaks of volatile organic compound in petroleum refineries, are implemented. NOTE: The following more stringent leak definitions shall be implemented: (R 336.1622(1), 40 CFR Part 60 Subpart GGGa)

a. Pumps 2,000 ppm instead of 10,000 ppm b. Valves in gas/vapor or light li quid service 500 ppm instead of 10,000 ppm

2. Permittee shall comply with the applicable require ments of 40 CFR Part 60, Subpart GGGa as soon as practicable after startup of the heavy oil upgrade project. (R 336.1622(1), (40 CFR 60.592(a)), 40 CFR Part 60 Subpart GGGa)

3. Permittee may elect to comply with the requirements of 40 CFR 60.483-1 and 483-2. (R 336.1622(1), (40 CFR 60.592(b))

4. Permittee may apply to the EPA Administrator for a det ermination of equivalency fo r any means of emission

limitation that achieves a redu ction in emissions of VOC at least equival ent to the reduction in emission of VOC achieved by the controls required in 40 CFR 60, Subpart GGG. In doing so, the permittee shall comply with the requirements of 40 CFR 60.484. (R 336.1622(1), (40 CFR 60.592(c))

5. Permittee shall comply with the provisions of 40 CFR 60.485 except as provided in 40 CFR 60.593. (R 336.1622(1), (40 CFR 60.592(d))

6. Permittee shall comply with the requirements of 40 CFR 60.486 and 487. (R 336.1622(1), (40 CFR 60.592(e))

7. Permittee subject to the provisions of Subpart GGG may comply with the following exemptions/provisions. (40 CFR 60.593)

a. Compressors in hydrogen service are exempt from the requirements of 40 CFR 63.648 (a) and (c) if the permittee demonstrates that a compressor is in hydrogen service. (40 CFR 60.593(b)(1)) b. Each compressor is presumed not to be in hydrogen service unless permittee demons trates that the piece of equipment is in hydrogen service. Fo r a piece of equipment to be considered in hydrogen service, it must be determined that the percentage hydrogen content can be reasonably expected always to exceed 50 percent by volume. For purposes of determining the per centage hydrogen content in the process fluid that is contained in or contacts a compressor, procedure s that conform to the general method described in ASTM E260-73, 91 or 96, E168-67, 77, or 92, or E 169-63, 77, or 93 shall be used (incorporated by reference as specified in 40 CR 60.17). (ASTM E260 is “Standard Practices for Packed Column Gas Chromatography”; ASTM E168 is ”Standard Practices for General Techniques of Infrared Quantitative Analysis”; E169 is “Standard Practices for General Techni ques of Ultraviolet – Visible Quantitative Analysis”; (40 CFR 60.593(b)(2)), (40 CFR 63.648(g)(2)(i)(A))Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 80 of 103



### TABLE F-1.11 {FG-PROCUNITS}

FLEXIBLE GROUPING REQUIREMENTS

c. Permittee may use engineering judgment rather than procedures in paragraph (b) of this condition to demonstrate that the percent content exceeds 50 percent by volume, provided the engineering judgment demonstrates that the content clearly exceeds 50 percent by volume. When the permittee and the Administrator do not agree on whether a piece of equi pment is in hydrogen service, the procedures in paragraph (b) shall be used to resolve the disagreement. (40 CFR 60.593(b)(3)(i)) d. If the permittee determines that a piece of equipment is in hydrogen service, the determination can be revised only by following the procedures in paragraph (b) of this condition. (40 CFR 60.593(b)(3)(ii)) e. Permittee may use the following provision in additi on to 40 CFR 60.485(e): Equipment is in light liquid service if the percent evaporated is greater t han10 percent at 150°C as determined by ASTM Method D86-78, 82, 90, 95, or 96 (incorporated by reference as specified in 40 CFR 60.18). (40 CFR 60.593(d)) f. Calculation of percentage leaking equipment comp onents for subpart VV of 40 CFR 60 may be done on a process unit basis or a sourcewide basis. Once the permittee has decided, all subsequent calculations shall be on the same basis unless a permit change is made. (40 CFR63.648(a)(2)) g. Reciprocating pumps in light liqui d service are exempt from 40 CFR 60.482 if recasting the distance piece or reciprocating pump replac ement is required. (40 CFR 63.648(f)) h. Reciprocating compressors are exempt from seal requirements if recasting the distance piece or compressor replacement is required. (40 CFR 63.648(i))

8. Permittee must maintain all records for a minimum of 5 years. (40 CFR 63.648(h))

9. Compliance with conditions 1-8 of this section shall be considered compliance with Michigan Air Pollution Control Rule R 336.1622 and the equipment leak standards in 40 CFR Part 63, Subpart CC-National Emission

Standards for Hazardous Air Pollutants from Petroleum Refineries.

10. The permittee shall comply with all applic able provisions of the following regulations: 40 CFR 60, Subpart VVa and Subpart GGGa: a. Pumps 2,000 ppm b. Valves in gas/vapor or light liquid service 500 ppm 40 CFR 63, Subpart CC, See Appendi x 1.7 of RO Permit 199700013c Michigan Air Pollution Control Rule R 336.1622

11. Permittee shall implement a program to monitor at least 90% of the flanges and connectors in gas/vapor and light liquid VOC service in the following emission units: EG70-COKER, EG71-H2PLANT, EG72-SULRBLOCK2, EG73-SOURWATER2, EG77-DHTHYTREAT, EG22-TANKFARMS, EG76-UTILITIES, and EG78-FUELGASRECOVERY. The program s hall meet the following requirements. (R 336.1205, R 336.1225, R 336.1226(d), R 336.1702(a), R 336.2802, 40 CFR 52.21) a. Monitoring shall be conducted on a quarterly basis, using test methods and procedures described in Appendix 1.5, Section D of RO Permit 199700013c. b. A leak shall be defined as an instrument reading of 500 ppm or greater, as sp ecified in NSPS Subpart VVa. c. Flanges and connectors may be excluded from the moni toring program if they are "unsafe to monitor" as defined in 40 CFR 60.482-7(g)(1), or "difficult to monitor" as defined in 40 CFR 60.482-7(h)(1). d. Permittee shall maintain records utilizing the pr ocedures in Appendix 1.4, Section E, of RO permit

199700013c.

12. Permittee shall implement a program to monitor at l east 50% of the flanges and connectors in gas/vapor and light liquid VOC service in the following emissi on units: EG04-VACUUM, EG05-CRUDE, EG08-GOHT, EG16-NAPHHYTREAT, EG19-KEROHYTREAT, EG14-C CRPLATFORMER, and EG21-CPTREATER. The program shall meet the following requirements. (R 336.1205, R 336.1225, R 336.1226(d), R 336.1702(a), R 336.2802) a. Monitoring shall be conducted on a quarterly basis, using test methods and procedures described in Appendix 1.5, Section D of RO Permit 199700013c. b. A leak shall be defined as an instrument reading of 500 ppm or greater, as sp ecified in NSPS Subpart VVa. c. Flanges and connectors may be excluded from the moni toring program if they are "unsafe to monitor" asMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 81 of 103



### TABLE F-1.11 {FG-PROCUNITS}

FLEXIBLE GROUPING REQUIREMENTS

defined in 40 CFR 60.482-7(g)(1), or "difficult to monitor" as defined in 40 CFR 60.482-7(h)(1). d. Permittee shall maintain records utilizing the pr ocedures in Appendix 1.4, Section E, of RO permit

199700013c.

* This requirement is state enforceable only.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 82 of 103



### TABLE F-1.14 {FG-CRUDETANKS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING This flexible group represents a co nsolidated requirement for external floating roof (EFR) tanks t hat are subject to 40 CFR Part 63, Subpart CC as Group 1 Vessels or subject to 40 CFR 60, Subpart Kb. These tanks may also be subject to Michigan Air Pollution Control Rule 623 (R 336.1623) and/or NSPS Subpart QQQ. This cons olidated requirement basically adopts NSPS Kb for these EFR tanks. Emission Unit/Process Groups EGTANK112, EGTANK113, EGTANK 114, EGTANK115, EGTANK129,

EGTANK130

I. DESIGN PARAMETERS

A. Pollution Control Equipment External Floating Roof

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d. Air

Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA
C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate
1. Crude oil 1. Throughput for FG-CRUDET ANKS shall not exceed a monthly average of 140,000 barrels per day. (R 336.1225)

B. Pollutants Maximum Emission Limit

1. NA 1. NA

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. The permittee shall perform inspections and monitor operating
information for FGCRUDETANKS in accordance with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A & Kb. (40 CFR Part 60 Subparts A & Kb)

2. The permittee shall keep record of inspections and operating

information for FGCRUDETANKS in accordance with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A & Kb. All records shall be kept on file for a period of at least five years and made available to the Department upon request. (40 CFR Part 60 Subparts A & Kb)

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. The permittee shall comply with all provisions of the Federal Standards

of Performance for New Stati onary Sources as specified in 40 CFR Part 60 Subparts A & Kb as they apply to FGCRUDETANKS. (40 CFR Part 60 Subparts A & Kb)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 83 of 103



### TABLE F-1.14 {FG-CRUDETANKS}

FLEXIBLE GROUPING REQUIREMENTS

2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. The permittee shall keep VOC emission calculations and monthly throughput records for FGCRUDETANKS. All records shall be kept on file for a period of at least five years and made available to the Department upon request. (R 336.1225, 40 CFR 52.21 (a) & (b))

IV. REPORTING
Reports and Schedules

V. OPERATIONAL PARAMETERS
1. The permittee shall maintain each storage tank in FGCRUDETANKS with the following equipment, or a deck and seal configuration that results in the sa me or lower VOC emissions from the tanks: (40 CFR 52.21 (a) & (b)) floating roof

welded deck mechanical shoe primary seal rim-mounted secondary seal

VI. OTHER REQUIREMENTS

NA
* This requirement is state enforceable only.



### TABLE F-1.15 {FG-NAPHTHATANKS}

FLEXIBLE GROUPING REQUIREMENTS

FLEXIBLE GROUPING This flexible group represents a cons olidated requirement for internal and external floating roof tanks that are subject to 40 CFR Part 63, Subpart CC as Group 1 Vessels or subject to 40 CFR 60, Subpart Kb. These tanks may also be subject to Michigan Air Pollution Control Rule 623 (R 336.1623) and/or NSPS Subpart QQQ. This cons olidated requirement basically adopts NSPS Kb for these tanks. Emission Unit/Process Groups EGTANK19, EGTANK40, EGTANK 45, EGTANK46, EGTANK47, EGTANK48, EGTANK49, EGTANK 53, EGTANK55, EGTANK57, EGTANK58, EGTANK61, EGTANK72, EGTANK101, EGTANK108, EGTANK109, EGTANK110, EGTA NK116, EGTANK128, EGTANK104, EGTANK120, EGTANK79, EGTANK135

I. DESIGN PARAMETERS

A. Pollution Control Equipment Internal Floating Roof External Floating Roof

B. Stack/Vent Parameters NA

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d. Air

Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA
C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate
NHT charge sweet naphtha 38,400 barrels per day monthly average 38,400 barrels per day monthly averageMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 84 of 103



### TABLE F-1.15 {FG-NAPHTHATANKS}

FLEXIBLE GROUPING REQUIREMENTS

reformate naphtha FCCU naphtha alkylate naphtha

ethanol coker naphtha gasoline 24,000 barrels per day monthly average 30,420 barrels per day monthly average 8,300 barrels per day monthly average 17,340 barrels per day monthly average 36,000 barrels per day monthly average 74,700 barrels per day monthly average (R 336.1225)

B. Pollutants Maximum Emission Limit

1. NA 1. NA

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. The permittee shall perform inspections and monitor operating

information for FGNAPHTHATANKS in accordance with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A & Kb. (40 CFR Part 60 Subparts A & Kb)

2. The permittee shall keep records of inspections and operating
information for FGNAPHTHATANKS in accordance with the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A & Kb. All records shall be kept on file for a period of at least five years and made available to the Department upon
request. (40 CFR Part 60 Subparts A & Kb)

B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. The permittee shall comply with all provisions of the Federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A & Kb as t hey apply to FGNAPHTHATANKS. (R 336.1702, 40 CFR Part 60 Subparts A & Kb) 2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. The permittee shall keep VOC emission calculations and monthly throughput records for FGNAPHTHATANKS. All records shall be kept on file for a period of at least five years and made available to the Department upon request. (R 336.1225, R 336.1702)

IV. REPORTING
Reports and Schedules

V. OPERATIONAL PARAMETERS
1. The permittee shall equip and maintain EGTA NK108, EGTANK109, EGTANK110, and EGTANK128 with slotted guidepole controls. (R 336.1225, R 336.1702)

2. The permittee shall maintain each storage tank in FGNAPHTHATANKS with the following deck and seal configuration, or a deck and seal c onfiguration that results in the same or lower VOC emissions from the

tanks: (R 336.1225, R 336.1702)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 85 of 103



### TABLE F-1.15 {FG-NAPHTHATANKS}

FLEXIBLE GROUPING REQUIREMENTS

Equipment Type Deck Primary Seal Secondary Seal EGTANK19 Internal floating roof Welded Mechanical Shoe None EGTANK40 Internal floating roof Welded Mechanical Shoe None EGTANK45 Internal floating roof Bolted Vapor Mounted Rim - Mounted EGTANK46 Internal floating roof Bolted Vapor Mounted Rim - Mounted EGTANK47 Internal floating roof Bolted Vapor Mounted Rim - Mounted EGTANK48 Internal floating roof Bolted Vapor Mounted Rim - Mounted EGTANK49 Internal floating roof Welded Mechanical Shoe None EGTANK53 Internal floating roof Welded Mechanical Shoe None EGTANK55 Internal floating roof Welded Mechanical Shoe None EGTANK57 Internal floating roof Welded Mechanical Shoe None EGTANK58 Internal floating roof Welded Mechanical Shoe None EGTANK61 Internal floating roof Welded Mechanical Shoe None EGTANK72 Internal floating roof Bolted Vapor Mounted Rim - Mounted EGTANK101 Internal floating roof Welded Mechanical Shoe None EGTANK108 External floating roof Welded Mechanical Shoe Rim - Mounted EGTANK109 External floating roof Welded Mechanical Shoe Rim - Mounted EGTANK110 External floating roof Welded Mechanical Shoe Rim - Mounted EGTANK116 Internal floating roof Welded Liquid Mounted None EGTANK128 External floating roof Welded Mechanical Shoe Rim - Mounted EGTANK79 Internal floating roof Welded Mechanical Shoe None EGTANK104 Internal floating roof Welded Mechanical Shoe None EGTANK120 Internal floating roof Welded Mechanical Shoe None EGTANK135 Internal floating roof Welded Mechanical Shoe None

VI. OTHER REQUIREMENTS

NA
* This requirement is state enforceable only.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 86 of 103



## FG-COOLTOWERS

FLEXIBLE GROUP CONDITIONS

DESCRIPTION These requirements apply to the cooling towers that are ne w or being modified as part of the heavy oil upgrade project (HOUP): D, E, G, H, and the new cooling tower. These requirements also apply to existing cooling towers that are not being modified as part of the HOUP: A, C, and F.

Emission Units: EGCOOLTOWERA, EGCOOLTOWERC, EGCOOLTOWERD, EGCOOLTOWERE, EGCOOLTOWERF, EGCOOLTOWERG, EGCOOLTOWERH, and EGCOOLTOWERNEW

Flexible Group ID: FGDHOUPANNUAL



### POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. Within 180 days after start-up of EG70-COKER, the per mittee shall submit, to the AQD District Supervisor, an inspection and maintenance program for each cooling tower in FG-COOLTOWERS. The permittee shall comply with the submitted program until the AQD Distri ct Supervisor approves the program or approves an amended program. Thereafter, the permittee shall comp ly with the approved program. At any time, the permittee may submit a modified program to the AQD District Supervisor for review and approval. 2
(R 336.1205, R 336.2802, 40 CFR 52.21)

2. Within 180 days after start-up of EG70-COKER, the pe rmittee shall submit, to the AQD District Supervisor, a program for monitoring each cooling tower in FG-COOLTOWERS for leaks of process fluids into the cooling water. The submitted program shall incl ude, as a minimum, all of the following: a. A description of the parameter or condition to be monitored and an explanation of how the selected parameter or condition will reliably indicate the presence of a leak. b. The parameter level(s) or conditions(s) that sh all constitute a leak. This shall be documented by data or calculations showing that the selected leve ls or conditions will reliably identify leaks. The monitoring must be sufficiently sensitive to determ ine the range of parameter levels or conditions when the system is not leaking. When the select ed parameter level or condition is outside that range, a leak is indicated. c. The monitoring frequency which shall be no less frequent than monthly for the first 6 months and quarterly thereafter to detect leaks.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 87 of 103

d. The records that will be maintained to document compliance with the requirements of this section.



### e. If a leak is detected, the permittee sha ll comply with the following requirements:


### i. The leak shall be repaired as soon as practical but not later than 45 calendar days after the permittee receives results of monitoring tests indicati ng a leak. The leak shall be repaired unless the permittee demonstrates that the results are due to a condition other than a leak. Once the leak has been repaired, the permittee shall c onfirm that the heat exch ange system has been repaired within seven calendar days of the repair or startup, whichever is later.



### ii. Delay of repair of heat exchange systems for wh ich leaks have been detected is allowed if the equipment is isolated from the process. Delay of repair is also allowed if repair is technically infeasible without a shutdown and any one of the following conditions are met. All of the following time periods shall be determined from the date when the permittee determines that delay of repair is necessary. 1. If a shutdown is expected within the next 2 months, a special shutdown before that planned shutdown is not required. Documentation of a decision to delay repair shall state the reasons repair was delayed and shall specify a schedule for completing the repair as soon as practical. 2. If a shutdown for repair would cause greater emissions than the potential emissions from delaying repair, the permittee may delay repa ir until the next shutdown of the process equipment associated with the leaking heat exch anger. The permittee shall document the

basis for the determination that a shutdown fo r repair would cause greater emissions than the emissions likely to result from delaying repair. 3. If a shutdown is not expected within the next 2 months, and the permittee delays repair because the necessary parts or personnel are not available, the permitee may delay repair up to a maximum of 120 calendar days. The permittee shall demonstrat e that the necessary parts or personnel were not available. The permittee shall comply with the submitted prog ram until the AQD District Supervisor approves the program or approves an amended program. Thereafte r, the permittee shall comply with the approved program. At any time, the permittee may submit a m odified program to the AQD District Supervisor for review and approval. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. The permittee shall equip and maintain each cooling tower in FG-COOLTOWERS with drift eliminators with

a vendor-certified maximum drift ra te of 0.005 percent or less. (R 336.1205, R 336.2802, 40 CFR 52.21)



### V. TESTING/SAMPLING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. Following issuance of this permit, but not later than 180 days after start-up of EG70-COKER, and every seven years thereafter, the permittee shall determine drift loss from EGCOOLTOWERA, EGCOOLTOWERC, EGCOOLTOWERD, EGCOOLTOWERE, EGCOOLTOWERF, EGCOOLTOWERG, and EGCOOLTOWERH by testing, at owner's expense, in accordance with Department requirements. The permittee shall use the 1994 version of the Cooling Te chnology Institute's Acceptable Test Code (ATC) 140, unless the AQD approves use of an alternate method. No less than 60 days prior to testing, the permittee shall submit a complete test plan to the AQD. Fo r tests conducted prior to start-up of EG70-COKER, the test plan shall demonstrate that test conditions will be representative of post-s tartup conditions. The AQD must approve the final plan prior to testing. Determinat ion of drift loss includes the submittal of a complete report of the test results to the AQD within 60 days following the last date of the test. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

2. Within 180 days after start-up of EG70-COKER, a nd every seven years thereafter, the permittee shall determine drift loss from EGCOOLTOWERNEW by testi ng, at owner's expense, in accordance with Department requirements. The permittee shall use the 1994 version of the Cooling Technology Institute's Acceptable Test Code (ATC) 140, unless the AQD approv es use of an alternate method. No less than 60 days prior to testing, the permittee shall submit a co mplete test plan to the AQD. The AQD must approve the final plan prior to testing. Determination of drif t loss includes the submittal of a complete report of theMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 88 of 103

test results to the AQD within 60 days following the last date of the test. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)



### VI. MONITORING/RECORDKEEPING Records shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

1. For each cooling tower in FG-COOLTOWERS, the perm ittee shall maintain a record, for the life of the cooling tower, of the vendor’s ce rtification required in SC IV.1. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

2. The permittee shall monitor the following for each cooling tower in FG-COOLTOWERS. 2 (R 336.1205, R 336.2802, 40 CFR 52.21) a. On a weekly basis, parameters needed to det ermine the total dissolved solids content of the circulating water. b. On a monthly basis, parameters needed to determine the water recirculation rate.

3. The permittee shall calculate the PM and PM-10 emission rates from each cooling tower in FG-COOLTOWERS monthly, for the preceding 12-month ro lling time period, using a method acceptable to the AQD District Supervisor. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

4. The permittee shall keep, for each cooling tower in FG-COOLTOWERS, a record of the date the two most

recent drift loss determinations were conducted. This re cord shall be maintained fo r more than five years if

necessary. (R 336.1205, R 336.2802, 40 CFR 52.21)



### VII. REPORTING

1. If the permittee invokes the delay of repair provisio ns for a heat exchange system, the following information shall be submitted in the next semi-annual periodic repo rt required by 40 CFR 63.152(c). If the leak remains unrepaired, the information shall also be submitted in each subsequent periodic report, until repair of the leak is reported. (R 336.1205, R 336.2802, 40 CFR 52.21) a. The permittee shall report the presence of t he leak and the date that the leak was detected. b. The permittee shall report whethe r or not the leak has been repaired. c. The permittee shall report the reason(s) for delay of repair. If delay of repair is invoked because a shutdown for repair would cause greater emissi ons than the potential emissions from delaying repair, documentation of emissions estimates must also be submitted. d. If the leak remains unrepaired, the permi ttee shall report the expected date of repair. e. If the leak is repaired, the pe rmittee shall report the date the leak was successfully repaired.



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. NAMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 89 of 103



### IX. OTHER REQUIREMENT(S)

1. NA

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).Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 90 of 103



## FG-FirePumps

EMISSION UNIT CONDITIONS

DESCRIPTION Two diesel-driven fire water booster pumps

Emission Units: 

### EG24P1, EG24P2

Flexible Group ID: FGDHOUPANNUAL



### POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. The permittee shall comply with all provisions of the federal Standards of Performance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and IIII, as they apply to each engine in FG-FirePumps. 2 (40 CFR Part 60 Subparts A & IIII)

2. The permittee shall maintain each engine in FG-FirePumps according to manufacturer’s recommendations, to ensure that the emissions from each engine cont inue to meet the certified values in SC IV.1. 2
(R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.4211)



### IV. DESIGN/EQUIPMENT PARAMETER(S)

1. The permittee shall only install engines in FG-FireP umps that have been certified by the manufacturer, using the procedures of 40 CFR Part 89 Subpart E, to meet or exceed the emission standards in 40 CFR 89.112 listed below, as in effect for model year 2007. a. PM10: 0.20 gram per kilowatt-hour 2 (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.4205) b. CO: 3.5 grams per kilowatt-hour 2 (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.4205)

c. NO X and non-methane hydrocarbons: 4.0 grams per kilowatt-hour 2 (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.4205)

2. The permittee shall equip and maintain each engine in FG-FirePumps with a non-resettable hour meter. 2
(R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR 60.4209)Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 91 of 103



### 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 monitor emissions and operating information for each engine in FG-FirePumps in

accordance with the federal Standards of Perform ance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and IIII. 2 (R 336.1205, R 336.1225, R 336.1702, R 336.1901, 40 CFR Part 60 Subparts A & IIII)

2. For each engine in FG-FirePumps, the permittee shall maintain a record, for the life of the engine, of the manufacturer’s certification required in SC IV.1. 2 (R 336.1205, R 336.2802, 40 CFR 52.21)

3. The permittee shall keep records of emissions an d operating information to comply with the federal

Standards of Performance for New St ationary Sources as specified in 40 CFR Part 60 Subparts A and IIII. 2
(40 CFR Part 60 Subparts A & IIII, R 336.1205)



### VII. REPORTING

1. The permittee shall provide written notification of c onstruction and operation to comply with the federal Standards of Performance for New Stationary Sources, 40 CFR 60.7. The permittee shall submit this
notification to the AQD District Supervisor within the time frames specified in 40 CFR 60.7. 2 (40 CFR 60.7)



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements

1. SVEngine1 6 2 10 2 R 336.1225 2. SVEngine2 6 2 10 2 R 336.1225



### IX. OTHER REQUIREMENT(S)

1. NA

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).Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 92 of 103



## FGDHOUPANNUAL

FLEXIBLE GROUP CONDITIONS

DESCRIPTION These emission units and flexible groups used the Actual-t o-Potential test for PSD applicability. The emission limits in this group serve to limit the Potential to Emit of covered equipment.



### Emission Units/Flexible Groups: EG11-FCCU, EG14-CCRPLCATREG, EG21-S2OFFGAS, FG29-IGF, EG42-43SULRECOV, EG 70-COKER, EG-COKERFLARE, EG72-SULRBLOCK2, FG-HEATERS, FG-PROCUNITS, FGCOOLTOWERS, FGFIREPUMPS, FGHOUPTANKS, EG71-H2STEAMSYS

POLLUTION CONTROL EQUIPMENT

I. EMISSION LIMIT(S)

Pollutant Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. PM 122.4 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

2. PM10 206.8 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

3. NO X 642 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

4. SO 2 373 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

5. CO 251.5 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

6. VOC 465 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

7. H 2 SO4 24.25 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

8. H 2 S 8.57 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21

9. Total reduced sulfur (TRS) 9.86 tpy Rolling 12-month time period * FGDHOUPANNUAL SC VI.1 R 336.1205, R 336.2802,
40 CFR 52.21 * Rolling 12-month time period as determined at the end of each calendar month.

Limits on the units and processes put in place in this permit for the operation of the facility will not cause a

combination of increases or decreases t hat would violate the netting conclusion.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 93 of 103



### II. MATERIAL LIMIT(S)

Material Limit Time Period/ Operating

Scenario Equipment Monitoring/ Testing Method Underlying Applicable Requirements

1. NA NA NA NA NA NA



### III. PROCESS/OPERATIO NAL RESTRICTION(S)

1. NA



### IV. DESIGN/EQUIPMENT PARAMETER(S)

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 calculate the PM, PM10, NO X , SO 2 , CO, VOC, H 2 SO4, H 2 S, and TRS emission rates from FGDHOUPANNUAL monthly, for the preceding 12-month rolling time period, using a method acceptable to the AQD District Supervisor, considering the following. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 51 Appendix S) a. For storage tanks, the permittee may maintain VOC emission calculations and monthly throughput records in lieu of performing monthly VOC calculations. b. CO emissions during periods of startup, shutdown, and malfunction for each emission unit in

FG-HEATERS without a CO CEMS shall be calculated at 400 ppmv at 3 percent excess oxygen. For each emission unit in FG-HEATERS without a CO CEMS, for which the permittee has collected CO emissions data during startup, s hutdown and malfunction periods from representative process heaters, the permittee may, after submitting a demonstration to the AQD District Supervisor that the emission data is representative, use the representative process heater data for calculating the CO emission rate

from that emission unit. c. VOC, H 2 S, and TRS emissions from cooling towers shall be calculated for periods of leaks of process fluids into the cooling water.

d. H 2 S and TRS emissions from EG72-SULRBLOCK2 shall include the emissions resulting from nonoperation of the sulfur pit degassing system. e. Fugitive emissions from all components that may leak, such as those addressed in leak detection and repair programs.

f. H 2 S and TRS emissions from sulfur recovery and loading operations. g. All emission calculations shall include emissi ons from startups, shutdowns, and malfunctions.

h. The data obtained from the sulfur content sa mpling program for various sulfur laden products and
process streams. i. Emissions resulting from the steam to hydrocarbon ration not being maintained at the appropriate level

for each flare.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 94 of 103



### VII. REPORTING

1. Within 30 days after completion of the installation, construc tion, reconstruction, relo cation, or modification authorized by this Permit to Install, the permittee or the authorized agent pursuant to Rule 204, shall notify the AQD District Supervisor, in wr iting, of the date of completion of the activity. Completion of the installation, construction, reconstruction, relocation, or modification is considered to occur not later than 180 days after the start-up of EG-70COKER. (R 336.1216(1), R 336.1201(7)(a))



### VIII. STACK/VENT RESTRICTION(S)

The exhaust gases from the stacks listed in the table bel ow shall be discharged unobst ructed vertically upwards

to the ambient air unless otherwise noted:

Stack & Vent ID Maximum

Exhaust

Dimensions

(inches) Minimum Height

Above Ground (feet) Underlying Applicable Requirements



### IX. OTHER REQUIREMENT(S)

1. NA

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).Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 95 of 103



### TABLE B-1

SOURCE-WIDE REQUIREMENTS

I. DESIGN PARAMETERS

A. Pollution Control Equipment NA

B. Stack/Vent Parameters Exhaust gases shall be discharged unobstructed vertically upwards unless

otherwise noted.

Stack/Vent ID a. Minimum Height (feet) b. Maximum

Exhaust

Dimension

(inches) c. Temp (°F) d.

Air Flow

Rate (acfm) Applicable Requirement

1. NA NA NA NA NA NA C. Other Design Parameters

1. NA

II. MATERIAL USAGE/EMISSION LIMITS

A. Material Maximum Usage Rate

1. NA 1. NA

B. Pollutants Maximum Emission Limit

1. NA 1. NA

III. COMPLIANCE EVALUATION Records of all of the following shall be maintained on file for a period of five years. (R 336.1213(3)(b)(ii))

A. MONITORING/RECORDK EEPING (R 336.1213(3))

1. Continuous Emission Monitoring (CEM) System and Recordkeeping 1. NA

2. Process Monitoring System and Recordkeeping 1. NA

3. Other Monitoring and/or Recordkeeping 1. The permittee shall conduct an enhanc ed air monitoring program at the facility to address citizen concerns. The permittee shall monitor concentrations of carbon monoxide, PM-10, sulfur dioxid e, volatile organic compounds (TO-15 canister method – subset to be determined and approved in the enhanced air monitoring program), and total reduced su lfur at no less than four sites in a manner and with instrumentation approv ed by the AQD Air Monitoring Unit. No less than 180 days after beginning construction pursuant to Permit to Install No. 63-08, the permittee shall submit a monitoring plan for the enhanced air monitoring program to the AQD Air Monitoring Unit. Following approval of a plan, the permittee shall begin monitoring all required pollutants, according to the approved plan, no late r than the date of startup of the heavy oil upgrade project. Monitoring shall continue for at least ten years. * (R 336.1901)

2. The permittee shall keep records of a ll air monitoring data collected in the air monitoring program. The permittee shall submit all records to the AQD Air Monitoring Unit in an acceptable format within 45 days following the end of the quarter in which the data were collected. * (R 336.1901)
B. TESTING/RECORDKEEPING (R 336.1213(3))

1. Parameter to be Tested/

Recorded 1. The permittee shall keep monthly and 12-month rolling time period records of the hours of operation of ea ch non-continuous drain. (R 336.1205, R 336.2802, 40 CFR 52.21) 2. Method/Analysis 1. NA 3. Frequency and Schedule of Testing/Recordkeeping 1. NAMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 96 of 103



### TABLE B-1

SOURCE-WIDE REQUIREMENTS

IV. REPORTING Reports and Schedules 1. The installation and modification of al l emissions units designated as part of the DHOUP, and all projects resulting in emissions decreases necessary to ensure that this project is minor unde r the New Source Review regulations, shall be completed no later than 180 days from the start-up of EG-70COKER. This shall be considered the completion of DHOUP construction, and the end of the contemporaneous period for this project. (R 336.1205, R 336.2802, 40 CFR 52.21, 40 CFR Part 51 Appendix S)

V. OPERATIONAL PARAMETERS
1. The permittee shall not operate any non-continuous drain for more than 100 hours per 12-month rolling time period, as determined at the end of each calendar month. (R 336.1205, R 336.2802, 40 CFR 52.21)

VI. OTHER REQUIREMENTS

1. The conditions contained in this RO Permit for wh ich a Consent Decree is the only identified applicable requirement shall be considered null and void upon the effe ctive date of termination of the Consent Decree. The

effective date of termination is defin ed for the purposes of this condition as the date upon which the Stipulation and Order for Termination is signed by a Circuit Court Judge. (R 336.1213(3))

2. Permittee shall comply with the requirements of the Consent Decree No. 01-40119 between United States of America (Plaintiff) and County of Wayne, Michigan, State of Louisiana, State of Minnesota (Plaintiff-Interveners) v. Marathon Ashland Petroleum, LLC (Defendant), and revisions thereto. (R 336.1213(3))

3. Each Responsible Official shall certify annually, using the format in Appendix 8 of RO Permit 199700013c, that the stationary source is in compliance with all stationary sour ce-wide requirements. This certification shall be included as part of the annual certification of compliance as require d in General Conditions 28 and 29 in Part A of the RO

Permit. (R 336.1213(4)(c))

4. Permittee shall comply with the Fugitive Dust Contro l Program dated December 27, 1996 and revisions thereto. (R 336.1213(3))

5. Permittee shall comply with all applicable requireme nts of 40 CFR Part 63, National Emission Standards for

Hazardous Air Pollutants for Source Cat egories, Subpart A-General Provisions. (40 CFR 63, Subpart A)

6. Permittee shall comply with all applicable requirem ents of 40 CFR Part 63, S ubpart CC-National Emission

Standards for Hazardous Air Pollutants from Petroleum Refineries. (40 CFR 63, Subpart CC)

7. Permittee shall comply with all applicable requirement s of 40 CFR Part 61, National Emission Standards for Hazardous Air Pollutants, S ubpart A-General Provisions. (40 CFR 61, Subpart A)

8. Permittee shall comply with all applicable requir ements of 40 CFR Part 61, National Emission Standards for Hazardous Air Pollutants, Subpart M-National Emission Standard for Asbestos. (40 CFR 61, Subpart M)

9. Permittee shall comply with all applicable requirement s of 40 CFR Part 61, National Emission Standards for Hazardous Air Pollutants, Subpart FF-National Emission Standard for Benzene Waste Operations. (Paragraph 18 and 19 of Consent Decree No. 01-40119), (40 CFR 61, Subpart FF), (Consent Decree No. 01-40119)

10. Permittee shall comply with all applicable requirement s of Natural Resources and Environmental Protection Act, Act 451 of 1994, Subpart 324.5524. (Act 451, Part 55, 324.5524)

11. Permittee shall not cause or allow the emission of any volatile organic compound from any process unitMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 97 of 103



### TABLE B-1

SOURCE-WIDE REQUIREMENTS

turnaround at the facility, unless such emission is controlled by one of the following methods: a. Capture and disposal in a fuel gas system.

b. Combustion in a smokeless flare. c. Any method approved by the Division that recovers no less than 90%, by weight, of the uncontrolled volatile organic compounds that would otherwis e be emitted into the atmosphere. (R 336.1616(1)(a, b & c))

12. Permittee shall comply with the provisions of R336.1616 un til the pressure of all vessels in the system is less than 5 psi gauge. (R 336.1616(2))

13. Except as provided for in conditi on 14, permittee shall notify the Division not less than 30 days before any process unit turnaround subject to the provisions of R336.1616. (R 336.1616(3))

14. In the case of process unit turnar ounds caused by circumstan ces beyond the control of the permittee, the Division shall be notified as soon as reasonably possible. (R 336.1616(4)), (R 336.1213)(3)

Note: Process Unit Turnarounds, for this ROP, are defined as “planned and scheduled shutdowns in which the entire process unit is shutdown and deinvento ried for major maintenance activities”.

15. Permittee shall comply with all applicable requirem ents of 40 CFR Part 63, Subpa rt UUU-National Emission
Standards for Hazardous Air Pollutants for Petroleum Refi neries: Catalytic Cracking Un its, Catalytic Reforming Units, and Sulfur Recovery Units. (40 CFR 63, Subpart UUU)

16. The provisions of Rule 406(2) are ap plicable requirements for the permittee. (R 336.1406(2))

17. The permittee shall conduct a program of enhanced sweeping of paved roads in the vicinity of the Detroit refinery. No less than 180 days after beginning construction pursuant to Permit to Install No. 63-08, the permittee shall submit a plan for the enhanced street sweeping program to the AQD District Supervisor as a proposed revision to the Fugitive Dust Control Program required in Table B- 1 of RO Permit 199700013c. The plan shall include the location, frequency, and estimated PM and PM-10 benefits of the program. The permittee shall begin enhanced sweeping, according to the plan, no late r than the date of startup of the heavy oil upgrade project. At any time, the permittee may submit a modified plan to the AQD District Supervisor. (R 336.1901)

18. The permittee shall notify the Department if a change in land use occurs for property classified as industrial or as a public roadway, where this classification was relied upon to demonstrate compliance with Rule 225(1) for the heavy oil upgrade project. The permittee shall submit the notification to the AQD Dist rict Supervisor within 30 days of the actual land use change. Within 60 days of the land use change, the permittee shall submit to the AQD District Supervisor a plan for complying with the requireme nts of Rule 225(1). The plan shall require compliance with Rule 225(1) no later than one year after the due date of the plan submittal. (R 336.1225(4))

19. The permittee shall comply with all provisions of the federal Standards of Perform ance for New Stationary Sources as specified in 40 CFR Part 60 Subparts A and Ja, as they apply to the facility. (40 CFR Part 60 Subparts A & Ja)

20. No later than startup of EG-70COKER, as defined in R 336.1119(p), the permi ttee shall permanently cease operating DHT compressors 1, 2, and 3, FCCU comp ressor 6, EG17-BTPLCHARHTR, EG17-BTPLINTRHTR, EG17-BTPLATFORMR, and EG07-DHTCHARHTR, and shall cont rol emissions from 29 pressure relief valves to atmosphere in the LPG Tank Farm. (R 336.1205, R 336.2802, 40 CFR 52.21)

21. Within 180 days after commencement of trial operation, the permittee shall submit to the AQD a sulfur content sampling plan for sulfur-laden process streams and products for the process units and products listed below. The plan shall consider catalyst life (“start of run” and “ end of run” conditions) for t he affected process units and products. The purpose of this sampling plan is to verify the sulfur distributions in the process simulations relied on in the permit application. (R 336.1205, R 336.1225, R 336.2802, 40 CFR 52.21)

• Crude unit

• Vacuum unitMarathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 98 of 103



### TABLE B-1

SOURCE-WIDE REQUIREMENTS

• Coker and coker gas plant

• Naphtha hydrotreater

• Distillate hydrotreater

• Kerosene hydrotreater

• Gasoil hydrotreater

• Sulfur recovery units, including sulfur st orage tanks and rail car loading operations

• Asphalt produced

22. Within 180 days after commencement of trial operation, the permittee shall submit to the AQD a sulfur content sampling plan for sulfur-laden process streams, products, sour water streams, and sulfur laden gaseous streams for the process units and products listed below. The plan sha ll consider catalyst life (“star t of run” and “end of run” conditions) for the affected process units and products. Sampling under the plan must occur at least annually. The purpose of this sampling plan is to verify the sulfur distributions in the process simulations relied on in the permit application. 3 (R 336.1201(3))

• Crude unit

• Vacuum unit

• Coker and coker gas plant

• Naphtha hydrotreater

• Distillate hydrotreater

• Kerosene hydrotreater

• Gasoil hydrotreater

• Sulfur recovery units, including tail gas units, sulfur storage tanks and rail car loading operations

• Asphalt produced

3 This condition is included at the request of the permittee.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 99 of 103

APPENDIX A

NO X , SO 2 , O 2 and CO Monitoring Continuous Emission Monitoring Sy stem (CEMS) Requirements

1. Within 30 calendar days after commencement of trial operation, the permittee shall submit two copies of a Monitoring Plan to the AQD, for review and approval. The Monitoring Plan shall include drawings or specifications showing proposed locations and descriptions of the required CEMS.

2. Within 150 calendar days after commencement of tria l operation, the permittee shall submit two copies of a complete test plan for the CEMS to the AQD for approval.

3. Within 180 calendar days after commencement of trial operation, the permittee shall complete the installation and testing of the CEMS.

4. Within 60 days of completion of testing, the permit tee shall submit to the AQD two copies of the final report demonstrating the CEMS complies with the requirements of the corresponding Performance Specifications (PS) in the following table.

Pollutant Applicable PS

NO X 2

SO 2 2

O 2 3

CO 4

5. The span value shall be 2.0 times the lowest emission standard or as specified in the federal regulations.

6. The CEMS shall be installed, calibrated, maintained, and operated in accordance with the procedures set forth in 40 CFR 60.13 and PS 2 of Appendix B to 40 CFR Part 60.

7. Each calendar quarter, the permittee shall perform the Quality Assurance Procedures of the CEMS set forth in Appendix F of 40 CFR Part 60. Within 30 days following the end of each calendar quarter, the permittee shall submit the results to the AQD in t he format of the data assessment report (Figure 1, Appendix F).

8. In accordance with 40 CFR 60.7(c) and (d), the permittee shall submit two copies of an excess emission report (EER) and summary report in an acceptable form at to the AQD, within 30 days following the end of each calendar quarter. The Summary Report shall follo w the format of Figure 1 in 40 CFR 60.7(d). The EER shall include the following information:

a) A report of each exceedance above the limits specifi ed in the conditions of this permit. This includes the date, time, magnitude, cause and corrective action s of all occurrences during the reporting period.

b) A report of all periods of CE MS downtime and corrective action.

c) A report of the total operating time of the emission unit during the reporting period.

d) A report of any periods that the CEMS exceeds the instrument range.

e) If no exceedances or CEMS downtime occurred duri ng the reporting period, the permittee shall report

that fact.

The permittee shall keep all monitoring data on file for a period of at least five years and make them available to the AQD upon request.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 100 of 103

APPENDIX B Recordkeeping Provisions – Actual to Projected-Actual Applicability Test

All information in this Appendix shall be maintained pursuant to R 336.2818 and 40 CFR 52.21(r)(6)(i) for 10 years after the emission units identified in Table C re sume normal operations, and shall be made available to the Department upon request.

A. Project Description:

The Detroit Heavy Oil Upgrade Project (Detroit HOUP) will expand the capacity of the Detroit Refinery and install new process units and support e quipment to allow the facility to refi ne a new source of crude oil. The proposed changes include the installation of a new delayed coker and coker gas plant, a new hydrogen plant and a second sulfur re covery unit, a replacement di stillate hydrotreater, new st orage tanks, a new flare system, a new cooling tower and changes to many of the existing process units at the refinery.

These changes are described in Permit to Install application number 63-08.

B. Applicability Test Description:

For all new emission units, the increase in actual emi ssions from the Detroit HOUP is based on the actualto-potential test. For most existing emission units in cluded in the Detroit HOUP, the potential to emit is based on requested maximum allowable emission rates as opposed to the maximum design capacity of the units, and the actual emissions increase due to the Detroit HOUP for those emission units was also based on the actual-to-potential calculation. The only exception to the use of t he actual-to-potential test is for the existing flare systems, included in FGREFINEFLARES in the permit.

C. Emission Units Using Actual-to-Projected Actual Test:

Emissions (tpy)

Emission Unit/Flexible Group ID Pollutant Baseline

Actual Projected

Actual Excluded Reason for

Exclusion

FGREFINEFLARES NOx 3.1 2.9 -

SO 2 23.2 3.3 -

VOC 13.5 6.9 -

CO 13.5 15.6 -

PM 0.08 0.08 -

PM10 0.31 0.31 -

H 2 SO 4 1.87 0.26 -

H 2 S 3.1 0.03

TRS 3.4 0.03

D. Emission Units Using Potential to Emit:

Emission estimates for the Detroit HOUP have used Potent ial to Emit for the following emission units/flexible

groups:

EG11-FCCU EG14-C CRPLCATREGEN EG21-S2OFFGAS

FG29-IGF EG42-43SULRECOV EG70-COKER

EG72-SULRBLOCK2 EG -COKERFLARE FG-HEATERS

FG-PROCUNITS FGCOOLTOWERS FGFIREPUMPS

FGHOUPTANKS

The flexible group FGDHOUPANNUAL has been created to account for the emissions from this group of equipment.Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 101 of 103

E. Netting Calculations and Discussion:

Emissions changes from the Detroit HOUP are summarized below. The Detroit HOUP emissions include the projected actual emissions from the existing refi nery flares. In cases where the project emissions exceed their regulatory significance threshold, a ne tting analysis was conducted whereby the sum of the contemporaneous emission increases and decreases were combined with the Detroit HOUP emissions to determine the net emissions impact. Emission decrease s associated with a feder al Consent Decree are not creditable in determining the net emissions impact and have been excluded from the calculation.

Detroit HOUP Net Emissions Changes (tons per year)

VOC NOx SO 2 PM PM10 CO H 2 SO 4 H 2 S TRS

Detroit HOUP -36 198 210 33 -13 85 13 3 3

Contemporaneous Increases 54 91 8 10 18 0 1 - -

Contemporaneous Decreases 20 290 219 43 18 0 18 - -

Total -2 -1 -1 0 -13 85 -4 3 3

Significance Level 40 40 40 25 15 100 7 10 10

F. Pre-Construction Projection of Emissions:

The following table shows the pre-construction estima te of emissions from the Detroit HOUP. The table identifies the projected annual emission rate for emission units using the actual-to-projected actual test, and the potential emission rate for emission uni ts using the actual-to-potential test.

Detroit HOUP Pre-Construction Emissions Projection (tons per year)

VOC NOx SO 2 PM PM10 CO H 2 SO 4 H 2 S TRS

Projected emissions for units using actual-to-projected actual test (FGREFINEFLARES) 7 3 3 0.1 0.3 16 0.26 0.03 0.03

Potential to emit for units using actual-to-potential test (FGDHOUPANNUAL) 465 642 373 122.4 206.8 251.5 24.25 8.57 9.86

Detroit HOUP Total Projected

Emissions 472 645 376 122.5 207.1 270 24.51 8.60 9.89Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 102 of 103

G. Recordkeeping:

The annual records shall contain the following informati on and be presented in a format acceptable to the AQD Permit Section Supervisor:

Pre-construction projection of actual emissions for emission units using the actual-to-projected actual test (FGREFINEFLARES).

Calendar year actual emissions for emission units using the actual-to-projected actual test (FGREFINEFLARES).

Potential-to-emit for emission units using the actual-to-potential test (FGDHOUPANNUAL).

Detroit HOUP Annual Emissions Record (tons per year)

VOC NOx SO 2 PM PM10 CO H 2 SO 4 H 2 S TRS

Projected emissions for

units using actual-toprojected actual test (FGREFINEFLARES) 7 3 3 0.1 0.3 16 0.26 0.03 0.03

Potential to emit for units using actual-to-potential test (FGDHOUPANNUAL) 465 642 373 122.4 206.8 251.5 24.25 8.57 9.86

Detroit HOUP Preconstruction Projection 472 645 376 122.5 207.1 267.5 24.51 8.60 9.89

Actual emissions for units using actual-to-projected

actual test (FGREFINEFLARES)

Potential to emit for units using actual-to-potential test (FGDHOUPANNUAL) 465 642 373 122.4 206.8 251.5 24.25 8.57 9.86

Detroit HOUP Annual

Emissions for Calendar

Year (1)
(1) Sum of actual emissions for units using actual -to-projected actual test (FGREFINEFLARES) plus potential to emit for units using act ual-to-potential test (FGDHOUPANNUAL).Marathon Petroleum Company LP (A9831) January 11, 2012 Permit No. 63-08C Page 103 of 103

H. Netting Summary:

The net emissions for DHOUP shall be summarized bas ed on the calendar year actual emissions for all emission units associated with the project.

Detroit HOUP Emission Netting Summary (tons per year)

VOC NOx SO 2 PM PM10 CO H 2 SO 4 H 2 S TRS

Actual emissions for units using actual-to-projected

actual test (FGREFINEFLARES)

Actual emissions for units using actual-to-potential test (FGDHOUPANNUAL)

Detroit HOUP Actual

Emissions for Calendar

Year (1)

Detroit HOUP Baseline

Emissions 441 357 178 81 202.3 183 12.04 8.84 10.01

DHOUP Actual Emissions

minus Baseline Emissions (2)

Contemporaneous Emission

Increases (3), (4) 26 0 0 0 0 0 0 - -

Contemporaneous/Creditable

Emission Decreases (4), (5) -66 -290 -219 -43 -18 0 -18 - -

Other Contemporaneous

Increases/Decreases (6)

Net DHOUP Actual

Emissions Increase (Add four lines above)

PSD Significance Level 40 40 40 25 15 100 7 10 10

(1) Sum of actual emissions for units using actual-to- projected actual test (FGREFINEFLARES) plus actual emissions for units using actual-t o-potential test (FGDHOUPANNUAL) (2) Includes emission increases for several projects in contemporaneous period. (3) Excludes contemporaneous increases embedded in the line item for DHOUP Actual Emissions, including the 2005 expansion (see footnote 2). (4) Netting analysis was not required for hydrogen sulfide or total reduced sulfur compounds. (5) The creditable decreases for VOC include 46 tons per year due to cont rolling emissions from 29 pressure relief valves to atmosphere in the LPG Ta nk Farm that are included in the “Detroit HOUP” line

in the table in section E above. (6) Other emissions increases and decreases occurring during the contemporaneous period (after issuance

of the Permit to Install for the DH OUP but before startup of the DHOUP).