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Home My WebLink About20123172.tiff STATE OF COLORADO John W. Hickenlooper,Governor Christopher Di Urbina,a,MD,MPH tee,. o�co1`n Executive Director and Chief Medical Officer %�� Dedicated to protecting and improving the health and environment of the people of Colorado *44: p� a 4300 Cherry Creek Dr.S. Laboratory Services Division 1876 Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 P of Public Health http://www.cdphestate.co.us V t�ronment RECEIV C E I October 31, 2012 Mr. Steve Moreno WELD COUNTY Weld Count' Clerk COMMISSIONERS 1402 N 171 Ave. Greeley, CO 80631 Dear Mr. Moreno: The Air Pollution Control Division will publish a public notice for Marathon Oil Company. This public notice will be published in the Greeley Tribune on November 4, 2012. Thank you for assisting the Division by making the enclosed package (includes public notice, preliminary analysis, Air Pollutant Emission Notice(s) and draft permit(s)) available for public review and comment. It must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please forward any comment regarding this public notice to the address below. Colorado Department of Public Health and Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Attention: Ellen Evans Regards, Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division it �1J��/' AL it Gi,�, 2012-3172 - /L/ • /.. 4.-)L H L- ill-l- ,, ni.g STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina,MD, MPH 7/of co� Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado * i 4300 Cherry Creek Dr. S. Laboratory Services Division " - */// Denver,Colorado 80246-1530 8100 Lowry Blvd. 1g76 Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 P of Public Health http://www.cdphe.state.co.us and Environment Website Title: Marathon Oil Company—Tsubaki Hills 08-62-34-4H— Weld County Released to: The Greeley Tribune on October 31, 2012, published November 4, 2012 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT The Colorado Air Pollution Control Division declares the following proposed construction activity warrants public comment. Therefore, the Air Pollution Control Division of the Colorado Department of Public Health and Environment hereby gives NOTICE, pursuant to Section 25-7- 114.5(5), C.R.S. of the Colorado Air Quality Control Act that the Division received an application for an air pollution emission permit on the following proposed project and activity: Marathon Oil Company proposes to construct and operate an oil and natural gas exploration and production facility known as Tsubaki Hills 08-62-34-4H located at Section 34, Township 8N, and Range 62W in Weld County. The company has submitted an application requesting issuance of a federally enforceable synthetic minor source permit limiting the potential to emit. As a synthetic minor source the permit is subject to public comment per Regulation 3, Part B, Section III.C.1. The Division hereby solicits and requests submission of public comment from any interested person concerning the aforesaid proposed project and activities to comply with the applicable standards and regulations of the Commission for a period of thirty (30) days from the date of this publication. Any such comment must be submitted in writing to the following addressee: Oluwaseun Ogungbenle Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B I Denver, Colorado 80246-1530 Within thirty(30) days following the said thirty (30)-day period for public comment, the Division shall consider comments and, pursuant to Section 25-7-114.5(7)(a), either grant, deny, or grant with conditions, the emission permits. Said public comment is solicited to enable consideration of approval of and objections to the proposed construction of the subject project and activity by affected persons. A copy of the applications for the emission permits, the preliminary analysis of said applications, and accompanying data concerning the proposed project and activity are available for inspection at the office of the Clerk and Recorder of Weld County during regular business hours and at the office of the Air Pollution Control Division, Colorado Department of Public Health and Environment, 4300 Cherry Creek Drive South, Denver, Colorado. A copy of the draft permit and preliminary analysis are available on the Air Pollution Control Division's website at: http://www.colorado.gov/cs/Satellite/CDPHE-AP/CBON/125 1596498449 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Marathon Oil Company Permit Number 12WE2205 Source Name: Tsubaki Hills (TH) 08-62-34-4H Source Location: SESE Sec. 34, T8N, R62W Point 001 - Four(4)400 BBL fixed roof Condensate Storage Tanks Point 002 -Two (2) 400 BBL fixed roof Produced Water Storage Tanks Point 003 -One (1) Reciprocating Internal Combustion Engine for use as Pump Jack Driver Equipment Description: Point 004-One(1)Truck Loadout Operation Point 005 - Produced Gas from Separator and Heater Treater, controlled by an enclosed flare Point 006 - Fugitive emissions from valves,flanges, connectors, and other components AIRS ID: 123-99AB Date: 09/19/2012 Review Engineer: Oluwaseun Ogungbenle Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt * If tank is a true minor source at a true minor facility, it may be granted "Final Approval" without first being issued an Initial Approval permit Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? July 10, 2012 Section 4—Source Description AIRS Point Equipment Description Four(4) 400 bbl fixed roof atmospheric condensate storage tanks. Emissions from 001 these tanks are controlled by an MRW Enclosed 6'x25' flare stack with 95% control efficiency. Two (2) 400 bbl fixed roof atmospheric produced water storage tanks. These tanks are steel welded tanks for storing produced water until transported off-site. 002 Emissions from these tanks are controlled by an MRW Enclosed 6'x25' flare stack with 95% control efficiency. Page 1 One (1) Arrow, Model A62, Serial Number 6B11B003994, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 80 003 horsepower at 1800 RPM. This engine is equipped with a Non-Selective Catalytic Reduction (NSCR) system and an Air-Fuel ratio controller. This engine is used as a pump jack driver. 004 Truck Loadout of Condensate and Produced water. Produced Gas from 2-phase Separator and 3-phase separator/Heater Treater 005 controlled by a 6'x 25' enclosed MRW Flare (F-1 or, if needed, F-2) with a minimum destruction efficiency of 95%. F-1 is the main flare, while F-2 is a backup. 006 Fugitive emissions from valves,flanges, connectors, and other com onents Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria x Yes No pollutant? If"yes", for what pollutant? PKo CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes"the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Source used E&P Tanks model and site specific sampling to develop site-specific emission factors in lb/bbl units 002 State (CDPHE) default emission factors for produced water tanks in Weld County. 003 Emission Factors for NOx, CO, VOC, and formaldehyde are from Manufacturer Data. Emission Factors for PM, TSP, and HAPs are from AP-42, Table 3.2-3 004 AP-42, Table 5.2-1, equation 1 Emission Factors for NOx and CO are from Manufacturer Data. 005 Maximum gas vented to the flare along with VOC weight fraction to determine a site- specific emission factor. VOC E.F.= 25005.5 Ib/MMscf produced gas vented 006 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 36,500 BBL/yr condensate throughput 002 36,500 BBUyr produced water throughput 003 4.5 MMscf/yr Annual Fuel Consumption 004 73,000 BBUyr condensate and produced water throughput 005 73.0 MMscf/yr(0.205 MMscf/d) natural as venting to flare Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 28 --- 84 5 006 Flanges 24 --- 40 6 Open-Ended Lines 0 --- 1 0 Pump Seals 0 --- 2 0 Valves 19 --- 21 2 Other 11 --- 15 6 Page 2 Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 29,200 BBL/yr condensate throughput 2012 002 29,200 BBL/yr produced water throughput 2012 003 4.5 MMscf/yr Annual Fuel Consumption 2012 004 58,400 BBL/yr condensate and produced water throughput 2012 005 58.4 MMscf/yr natural gas venting to flare 2012 Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 28 --- 84 5 006 Flanges 24 --- 40 6 2012 Open-Ended 0 --- 1 0 Lines Pump Seals 0 --- 2 0 Valves 19 --- 21 2 Other 11 --- 15 6 Basis for Permitted Emissions (Permit Limits} AIRS Point Process Consumption/Throughput/Production 001 36,500 BBL/yr condensate throughput 002 36,500 BBL/yr produced water throughput 003 4.5 MMscf/yr Annual Fuel Consumption 004 73,000 BBL/yr condensate and produced water throughput 005 73.0 MMscf/yr(0.205 MMscf/d) natural gas venting to flare Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 28 --- 84 5 006 Flanges 24 --- 40 6 Open-Ended Lines 0 --- 1 0 Pump Seals 0 --- 2 0 Valves 19 --- 21 2 Other 11 --- 15 6 Does this source use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 MRW Technologies, 6'x 25' Enclosed Flare 95% 002 01 MRW Technologies, 6'x 25' Enclosed Flare 95% 99.9% HCHO Non-selective catalytic reduction (NSCR)system and air- 84% !kJ Ox 003 01 VOC fuel ratio controller. 17% CO17/o C 005 01 MRW Technologies, 6'x 25' Enclosed Flare 95%VOC and HAP Section 6— Emission Summary (tons per year) Point NOx VOC CO Single HAP Total HAP 001 ---- 8.9 ---- 0.52 (n-Hexane) 0.79 002 ---- 4.8 ---- 0.40 (n-Hexane) 0.53 PTE: 003 11.4 0.03 4.5 0.07 (Formaldehyde) 0.09 004 ---- 3.6 ---- 0.21 (n-Hexane) 0.33 005 ---- 913.0 ---- 26.0 (n-Hexane) 35.0 006 ---- 3.5 ---- 0.25 (n-Hexane) 0.75 Page 3 Total 11.4 933.8 4.5 27.4(n-Hexane) 37.5 0.07 (Formaldehyde) 001 ---- 7.43 0.44 (n-Hexane) 0.53 002 ---- 3.8 ---- 0.32 (n-Hexane) 0.42 003 11.4 0.03 4.5 0.07 (Formaldehyde) 0.09 Uncontrolled actual point source emission 004 ---- 3.6 ---- 0.21 (n-Hexane) 0.33 rate: 005 ---- 730.0 ---- 20.8 (n-Hexane) 28.0 006 ---- 3.2 ---- 0.12 (n-Hexane) 0.31 Total 11.4 748.0 4.5 21.9 (n-Hexane) 29.7 0.07 (Formaldehyde) 001 ---- 0.45 ---- 0.03 (n-Hexane) 0.04 002 ---- 0.24 ---- 0.02 (n-Hexane) 0.03 003 1.9 0.02 3.7 0.01 (Acetaldehyde) 0.02 Controlled point 004 ---- 3.62 ---- 0.21 (n-Hexane) 0.33 source emission rate: 005 14.3 45.64 23.9 1.3 (n-Hexane) 1.74 006 ---- 3.5 ---- 0.25 (n-Hexane) 0.75 Total 16.2 53.5 27.6 1.8 (n-Hexane) 2.9 0.01 (Acetaldehyde) Total Permitted 1.8 (n-Hexane) emissions (tpy): 16.2 53.5 27.6 0.01 (Acetaldehyde) 2.9 Note(s): 1. Uncontrolled Total HAP emissions for points 001 and 002 only reflect Benzene and n-Hexane emissions. 2. Controlled NOx and CO emissions for point 005 are from the combustion of the produced gas and tank vapors using the flare F-1. Section 7—Non-Criteria / Hazardous Air Pollutants AIRS Uncontrolled Are the Pollutant CAS# BIN Emission Rate emissions Controlled Emission (Iblyr) Point reportable Rate(Iblyr) Benzene 71432 A 198 Yes 10 Toluene 108883 C 160 No 8 001 Ethylbenzene 100414 C 18 No 1 Xylenes 1130207 C 59 No 3 n-Hexane 110543 C 870 No 44 2,2,4-Trimethylpentane 540841 C 61 No 3 002 Benzene 71432 A 204 Yes 10 n-Hexane 110543 C 642 No 32 Benzene 71432 A 9 No 9 Toluene 108883 C 3 No 3 1,3-Butadiene 106990 A 4 No 4 003 Formaldehyde 50000 A 139 Yes 0 Acetaldehyde 75070 A 16 No 16 Acrolein 107028 A 15 No 15 Methanol 67561 C 18 No 18 Benzene 71432 A 77 Yes 77 Toluene 108883 C 63 No 63 004 Ethylbenzene 100414 C 6 No 6 Xylenes 1130207 C 22 No 22 n-Hexane 110543 C 339 No 339 2,2,4-Trimethylpentane - 540841 C 23 No 23 Benzene 71432 A 6704 Yes 335 Toluene 108883 C 5045 Yes 252 005 Ethylbenzene 100414 C 717 No 36 Xylenes 1130207 C 1798 Yes 90 n-Hexane 110543_ C 41530 Yes_ 2077 - Benzene 71432 A 58 Yes 58 Toluene 108883 C 128 No 128 006 Ethylbenzene 100414 C 38 No 38 Xylenes 1130207 C 149 No 149 n-Hexane 110543 C 246 No 246 Page 4 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non- criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Section 9—Source Classification Is this a new previously un-permitted source? X Yes No 001 X True Synthetic Major Minor Minor 002 X True Synthetic Major Minor Minor True Synthetic What is this point classification? 003 X Minor Minor Major True Synthetic 004 X Minor Minor Major 005 True X Synthetic Major Minor Minor True Synthetic 006 X Minor Minor Major What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? Yes X No If"yes" what kind of modification? Minor Synthetic Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? Synthetic Minor for VOCs, n-Hexane, and Total HAPs For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.ii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? Page 5 AIRS Point Section 12— Regulatory Review Requlation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 001-006 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 -Smokeless Flare or Flares for the Combustion of Waste Gases: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Requlation 2—Odor • Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-006 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Requlation 3 -APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 001-006 each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is non-attainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions 001-006 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) Part B, III.D.2 - RACT requirements for new or modified minor sources located in ozone non-attainment areas: This source is located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 001-006 The date of interest for determining whether the source is new or modified is, therefore, November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the tank battery from which loadout is occurring commenced operation after the date above (04/09/2012), this source is considered "new or modified." Operator is using 0.6 saturation factor(for submerged fill); therefore, RACT requirements are satisfied. Regulation 6- New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 001&002 These tanks are not subject to NSPS Kb because they each have a capacity less than 471 BBL(19,800 gallons). NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ if their manufacture date is on or after July 1, 2008. 003 Engine manufacture date provided by applicant(June 21, 2011) is after July 1, 2008; therefore, this engine is subject to NSPS JJJJ. Specifically, this engine is subject to the requirements of 40 CFR 60.4233(d) and must comply with the emission standards for field testing in 40 CFR 1048.101(c). Page 6 NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities (any processing site engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids (NGLs) or both). 006 Is this source at a "natural gas processing plant?" No Is this source subject to NSPS KKK? No This facility is not a natural gas processing plant; therefore, it is not subject to NSPS KKK. Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS The condensate tank battery at this facility is subject to the emission control requirements 001 for condensate tanks because this facility is located in a non-attainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is not currently subject to this section because uncontrolled actual emissions of VOCs from this condensate tank battery are less than 20 tpy on a rolling 12-month total. 003 This engine is not subject to the emission standards in Regulation 7, Section XVII.E because its maximum horsepower rating (80 HP) is less than 100 HP. 004 This source does not load gasoline into transport vehicles; therefore, it is not subject to the requirements in Regulation 7, Section VI.C. Section XII.G: If facility is a natural gas processing plant located in non-attainment area, then it is subject to Section XII.G. 006 This facility is not a natural gas processing plant; therefore, it is not subject to this part. Regulation 8— Hazardous Air Pollutants 001, 002, MACT EEEE: Organic Liquids Distribution and 004 This source is not subject to MACT EEEE because it is not located at a major source of HAP. 001-006 MACT HH This source is not subject to MACT HH because it is not located at a major source of HAP. MACT 7777: Engines subject to area source MACT 7777 are engines with a commencement of construction date on or after June 12, 2006. 003 Based on the date of commencement of construction (4/9/2012), this pump jack engine is considered a new area source under MACT ZZZZ (i.e. the date of commencement of construction is after June 12, 2006). The requirements of MACT ZZZZ shall be satisfied by meeting applicable NSPS JJJJ requirements. Section 13—Aerometric Information Retrieval System Coding Information Process Emission Pollutant/ Fugitive Emission Factor Control Point Process Description Factor CAS# (Y/N) Source (%) 11.62 Site-specific/E&P lb/1000 gal VOC No Tanks 95 0.155 Benzene No E&P Tanks 95 lb/1000 gal 0.126 Toluene No E&P Tanks 95 lb/1000 gal 01 E&P Condensate 0.014 Ethylbenzene No E&P Tanks 95 001 Storage Tanks lb/1000 gal y 0.002 Xylenes No E&P Tanks 95 lb/1000 gal y 0.682 n-Hexane No E&P Tanks 95 lb/1000 gal 0.048 2,2,4-TMP No E&P Tanks 95 lb/1000 gal SCC 40400312—Fixed Roof Tank, Crude Oil,working+breathing+flashing losses Page 7 Point Process Process Emission Pollutant/ Fugitive Emission Factor Source Control Description Factor — CAS# (Y/N) (%) 0.262 lb/BBL VOC No State Default EF 95 throughput E&P Produced 0.007 01 Water Storage lb/BBL Benzene No State Default EF 95 002 Tanks throughput 0.022 lb/BBL n-Hexane No State Default EF 95 throughput SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing Point Process Process Emission Pollutant/ Fugitive Emission Factor Control Description Factor CAS# (Y/N) Source (%) 0.04 g/hp-hr VOC No Manufacturer 50.0 14.7 g/hp-hr NOx No Manufacturer 83.7 5.8 g/hp-hr CO No Manufacturer 17.2 Reciprocating 0.09 g/hp-hr Formaldehyde No Manufacturer 99.9 Internal 0.00279 01 Combustion lb/MMBtu Acetaldehyde No AP-42 NA 003 Engine 0.00263 lb/MMBtu Acrolein No AP-42 NA 0.00158 Benzene No AP-42 NA lb/MMBtu 0.00306 Methanol No AP-42 NA lb/MMBtu 0.000663 13 No AP-42 NA lb/MMBtu Butadiene 0.000558 Toluene No AP-42 NA lb/MMBtu SCC 20200253: Internal combustion Engines (Natural Gas, 4-cycle rich burn) Process Emission Pollutant/ Fugitive Control Point Process Description Factor CAS# (YIN) Emission Factor Source (%) 2.36 VOC No AP-42 NA lb/1000 gal 0.03 Benzene No AP-42 NA lb/1000 gal Condensate and 0'03 Toluene No AP-42 NA 01 Produced Water lb/1000 gal 004 Truck Loadout 0.003 Ethylbenzene No AP-42 NA lb/1000 gal 0.009 Xylenes No AP-42 NA lb/1000 gal y 0.14 n-hexane No AP-42 NA lb/1000 gal SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (Y/N) Emission Factor Source (%) 25005.5 VOC No VOC Wt. Fraction 95 lb/MMscf 0.3 NOx No Manufacturer NA lb/MMBtu 0.5 Flaring of lb/MMBtu CO No Manufacturer NA 005 01 produced gas and 114.795 tank vapors lb/MMscf Benzene No Engineering Calculation 95 86.397 Toluene No Engineering Calculation 95 lb/MMscf 12.274 Ethylbenzene No Engineering Calculation 95 lb/MMscf Page 8 30.795 Xylenes No Engineering Calculation 95 Ib/MMscf 711.137 n-Hexane No Engineering Calculation 95 Ib/MMscf SCC 31000205: Flares (Natural gas production) Point Process Process Emission Pollutant/ Fugitive Emission Factor Control Description Factor CAS# (YIN) Source (%) Fugitive VOC EPA-453/R- EPA-453/R-95- 01 Leak Emissions 95-017, VOC Yes 017, Table 2-4 NA 006 Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14— Miscellaneous Application Notes AIRS Point 001 Crude Oil Storage Tanks Site-specific emission factor using E&P Tanks: VOC = (8.91 TPY * 2000)/ 36500 bbl/yr= 0.4882 lb/bbl *1000/42 = 11.62 lb/1000 gal Benzene = 238 lb/yr/36500 bbl/yr= 0.0065 lb/bbl * 1000/42 = 0.155 lb/1000 gal Toluene = 193 lb/yr/ 36500 bbl/yr= 0.0053 lb/bbl * 1000/42 = 0.126 lb/1000 gal Ethylbenzene = 21 lb/yr/36500 bbl/yr= 0.00058 lb/bbl * 1000/42 = 0.014 lb/1000 gal Xylenes = 3 lb/yr/ 36500 bbl/yr= 0.00008 lb/bbl * 1000/42 = 0.002 lb/1000 gal n-Hexane = 1045 lb/yr/36500 bbl/yr= 0.0286 lb/bbl * 1000/42 = 0.682 lb/1000 gal 2,2,4-TMP = 74 lb/yr/ 109500 bbl/yr= 0.002 lb/bbl * 1000/42 = 0.048 lb/1000 gal VOC emissions were estimated using E&P Tanks and the Vasquez-Beggs equation. HAP emissions were estimated using the speciation reported in the Tank Vapor Composition obtained from the E&P Tanks output. In providing a rationale for their use of the Vasquez-Beggs equation, the operator claims: "Emission estimates using RVP Distillation method in E&P Tanks resulted in zero emissions. Therefore, flash emissions are calculated using the Vasquez-Beggs equation, and standing/working/breathing losses using AP-42 (stable oil) method in E&P Tanks. Total estimated tank emissions are the sum of the two." Furthermore, operator claims that"the requested emissions are based on maximum expected annual production and site-specific oil analysis." There are no testing requirements for this source since the liquids analysis that was included with this application was conducted within the last year. Page 9 AIRS Point 002 Produced Water Storage Tanks State-Developed Emission factors are: Produced Water Tank Default County Emission Factors (lb/bbl) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 0.262 0.007 0.022 Douglas, Jefferson, Larimer and Weld State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson, Larimer and Weld The operator stated on the APEN that the tanks contain less than 1% by volume crude oil on an annual average basis. According to operator, "...the produced water is injected in a commercial well and can't have crude in it." There is a categorical exemption for such sources (Regulation 3, Part B, Section II.D.1.m). However, Marathon Oil Company will not take advantage of this categorical exemption in order to be consistent with other facility wide permits for similar facilities. In a correspondence with Scott Park (Marathon Oil Company's contact for this permitting project), he said: "We have not been exempting the PW tanks for our other permits so let's keep this consistent on this one..." Marathon Oil initially calculated emissions from the produced water tanks using site-specific emission factors; however, Scott decided to go with the State default emission factors upon corresponding with him. The emissions calculated using CDPHE default emission factors are higher than the ones calculated using site-specific emission factors; therefore, they represent the worst case scenario. AIRS Point 003 Stationary RICE Based on the date of commencement of construction (4/9/2012), this pump jack engine is considered a new area source under MACT ZZZZ (i.e. the date of commencement of construction is after June 12, 2006). The requirements of MACT Z777 shall be satisfied by meeting applicable NSPS JJJJ requirements. Engine manufacture date provided by applicant(June 21, 2011) is after July,1, 2008; therefore, this engine is subject to NSPS JJJJ. Specifically, this engine is subject to the requirements of 40 CFR 60.4233(d) and must comply with the emission standards for field testing in 40 CFR 1048.101(c). However, this engine is not subject to the emission standards in Regulation 7, Section XVII.E because its maximum horsepower rating (80 HP) is less than 100 HP. This engine is controlled by an NSCR and AFRC. There are no performance testing requirements for this engine because it is being run in a certified manner. According to the guidance document for NSPS JJJJ, "If you operate and maintain the certified stationary SI internal combustion engine and control device according to the manufacturer's emission- related written instructions, you are operating in a certified manner." The control efficiency claimed for formaldehyde is unusually high (99.9%) and could have necessitated some testing requirements; however, I am not requiring formaldehyde testing because this is a small engine (i.e., the site-rated horsepower rating is only 80 hp) and the contribution of formaldehyde emissions from this engine (0.07 tpy) to the overall facility HAP emissions (29.7 tpy) is negligible. Page 10 AIRS Point 004 Truck Loadout of Crude Oil and Produced Water AP-42: Chapter 5.2 Equation 1 L = 12.46*S*P*M/T L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T = temperature of bulk liquid loaded [deg. R] S 0.6 Submerged loading: dedicated normal service P 4.5 Psia, M 36.45 lb/lb-mole T 520 deg. R L 2.36 lb/103 gal 0.10 lb/bbl Annual requested Throughput 73000 gal/yr Annual requested VOC emissions 7230 lb/yr 3.62 tpy Page 11 AIRS Point 005 Heater Treater/ F-1 & F-2 Produced gas (from the separator and heater treater) and tank vapors (from the condensate tank and produced water tank batteries) are routed to the MRW flare for destruction. VOC emissions from the condensate and produced water tanks are already captured under points 001 and 002, respectively; therefore, this point only shows VOC emissions from the heater treater gas that is routed to the flare. NOx and CO emissions from the flare are also captured under this point. In other words, the NOx and CO emissions shown on the general APEN for this point are post-combustion emissions from the flare. Emissions were calculated using VOC wt fraction. (scf/hr) * (Ib/Ib-mol) * (% fraction from sales gas analysis) / (379.482 scf/lb-mol) = lb/hr*(hr/yr) /2000 lb/T) =TPY VOC = (912.7 TPY*2000 lb/T) /(73.0 MMscf/yr) = 25005.5 lb/MMscf NOx and CO (from Manufacturer(NOx= 0.3 lb/MMBtu; CO = 0.5 lb/MMBtu)) Benzene = (8380 Ib/yr)/73.0 MMscf/yr= 114.795 lb/MMscf Toluene = (6307 Ib/yr) /73.0 MMscf/yr= 86.397 lb/MMscf Ethylbenzene = (896 Ib/yr) / 73.0 MMscf/yr= 12.274 lb/MMscf Xylenes= (2248 Ib/yr) /73.0 MMscf/yr= 30.795 lb/MMscf n-Hexane= (51913 Ib/yr) / 73.0 MMscf/yr= 711.137 lb/MMscf Also, operator will not be required to submit the results of a most recent extended gas analysis for this source because the extended gas analysis that was included with this application was conducted within the last year. However, as part of the periodic testing requirements, operator will be required to complete an extended gas analysis on annual basis. AIRS Point 006 Fugitive VOC Leak Emissions A hard count of components will not be required for this source because the most recent component count was conducted within the last year. Also, operator will not be required to submit the results of a most recent extended gas or extended gas liquids analyses because the extended gas and extended gas liquids analyses that were included with this application were conducted within the last year. However, as part of the periodic testing requirements, on annual basis, operator will be required to complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. The reason operator will be required to complete an extended natural gas liquids analyses is because they are claiming that the wt. % of VOC in their light oil is 93.91% (less than 100%). Facility All Facility wide review wide points A permit will be issued because the facility-wide uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and facility is synthetic minor source with respect to VOC, NANSR, n-Hexane, and total HAPS. The APENs associated with this permit application were prepared prior to the projected startup date (4/8/2012) and commencement of any operation at this facility; however, they were not signed until 07/09/2012. Therefore, although this facility commenced operation on 04/09/2012, the APENs still shows the projected startup date. Operator will be required to submit a Notice of Startup within 15 days of issuance of this permit. In their Ambient Air Impact Analysis for this facility, Marathon claims that although their NOx emission rate in lb/hr exceeds the short term modeling threshold listed in the State's Modeling Guideline, they are not subject to modeling requirements because, per PS Memo 10-01, only the 40 tpy threshold is currently considered to evaluate modeling requirements. Page 12 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BAT R (��F� Current Status(Check all that apply) 122J J9°IAg OO I Reason for ADEN Submittal i(Check all that apply) AIRS ID#': ❑ APEN update only s'‘\"]':::;® New or previously unreported battery 1: Modification to existing source' ,. \ ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GE0\ ❑ Synthetic minor facility &cancellation request for individual pemut6: ® Located in the 8-hr Ozone Control Area ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPO]. E Administrative permit amendment' ID Permitted under individual permit: NEZ2Os ❑ Other: For individual pemut applications,check if you want': ❑A copy of the preliminary analysis conducted by the Division ®To review a draft of die permit prior to issuance Company Names: Marathon Oil Company OGCC Operator#: 53650 Mailing Address10: 4557 Denrose Court City: Fort Collins State: CO Zip: 80524 E-mail: spark@marathonoil.com Contact Name: Scott Park Phone: (970)419-7809 Fax: Tank Battery Name": TH-08-62-34-4H Number of tanks: 4(2 in use) Location'(QQ Sec.Twp.Range.): SESE S34 T8N R62W County: Weld Total tank capacity[bbl]: 1600 bbl Calendar year for which"Actual"data applies": Projected Year(s)tank(s)were placed in service': 2012 Control Descriptions: MRW Technologies Flare Control Efficiency16: 95% Condensate Throughput"[bbl/year] Requested": 36,500 Maximum for PTE calculation19: 36,500 Actual'°: 29,200 While Controls Operational't 29,200 Other equipment at facility'': Produced Water Storage Tanks,Truck Loadout, Fugitives, Heater Treater Comments: Condensate throughputs are maximum projected.Tank ID's 5-11-060-TK25,-TK28,-TK33,and-TK36. Estimated emissions at throuehputs listed above. Use N/A for requested throughput/emission va/ties unless requesting an individual penal! ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emissionsl' Actual Emissions'`° Pollutant24 [lb/bbl] PTE" Uncontrolled'6 Controlled" Uncontrolled'6 Controlled" VOC[tons/year] N/A 8.91 8.91 0.45 7.43 0.37 NOx[tons/year] -- -- --- -- -- CO[tons/year] — -- --- -- Benzene[lbs/year] N/A 238 238 11.9 198 9.9 n-Hexane[lbs/year] N/A 1045 1045 52 870 44 Wells serviced by this tank or tank battery" API#: 05-123-33889 Name: Tsubaki Hills 08-62-34#4H ®Newly Reported Well API#: Name: D Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name ❑Newly Reported Well N). 'i' API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well 7 aThe sign.• e below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my o ]mowb.ge :nd belief. If this i a registra ion for coverage under general permit GP01,I further certify that this source is and will be operated in full o comp ianc i each cS'diti. .f gen a per at P01. 1—`912O(Z 2 Siena e of Legall Ant.orized Person(not a vendor or consultant) Date N Robert Nickola Operations Manager o Type or Print Name of Person Smiting Above Official Title n> I Submit this form, along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. 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O C V 1 C u C o m u y o c D ° e a C ° • E w 'c E T R Di O V Ot r A Ya ` ° y a y C e el w 'g p N N r r 9 ° q t, °.3'-'); ' U� m 1., ° ° r F .> U v C R = N O 0 ] N v o o ° - o L o E ° E R , Pr a _ _ �' o 0. c { U ,24 o G o C E C U O eyi ti 21 ,•a a 'GiR," W g F a W c ¢ a• mr co Q z m cc d u a o 41 m o t� " %m C ^ °� c m '� aoi o o E K a o E U a m K G O c ono .„ C E. 1 F m v W v' -, — c w a O c ,..5 .10" --,7., s c = c L fl .. ` U '0' o L-io c, F ro ^ ° ..o_. as > 2:I I✓ X U u r N G ,°® ca U w O a' > 0 u El a m STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT „�/ AIR POLLUTION CONTROL DIVISION t ;" * TELEPHONE: (303) 692-3150 1876** lgy6 CONSTRUCTION PERMIT PERMIT NO: 1 2WE22055 Issuance 1 DATE ISSUED: ISSUED TO: Marathon Oil Company THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and Natural gas exploration and production facility, known as Tsubaki Hills 08-62-34-4H, located in SESE Section 34, Township 8N, Range 62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point 5-11-060-TK25 Four (4) 400 bbl fixed roof atmospheric condensate storage 5-11-060-TK28 tanks. Emissions from these tanks are controlled by an 001 5-11-060-TK33 MRW Enclosed 6'x25' flare stack with 95% control efficiency. 5-11-060-TK36 5-11-060-TK29 Two (2) 400 bbl fixed roof atmospheric produced water storage tanks. These tanks are steel welded tanks for 5-11-060-TK32 002 storing produced water until transported off-site. Emissions from these tanks are controlled by an MRW Enclosed 6'x25' flare stack with 95% control efficiency. One (1) Arrow, Model A62, Serial Number 66116003994, natural gas-fired, naturally aspirated, 4SRB reciprocating E-01 003 internal combustion engine, site rated at 80 horsepower at 1800 RPM. This engine is equipped with a Non-Selective Catalytic Reduction (NSCR) system and an Air-Fuel ratio controller. This engine is used as a pump jack driver. Loadout 004 Truck loadout of condensate and produced water. Produced Gas from 2-phase Separator and 3-phase Heater separator/Heater Treater controlled by a 6'x 25' enclosed Treater, F-1 & 005 MRW Flare (F-1 or, if needed, F-2) with a minimum F-2 destruction efficiency of 95%. F-1 is the main flare, while F-2 is a backup. AIRS ID: 123/99AB Page 1 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 Facility AIRS Description Equipment ID Point Fugitive 006 Fugitive emissions from valves, flanges, connectors, and other components. The engine at point 003 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow A62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the APCD no later than fifteen days after issuance of this permit by submitting a Notice of Startup (NOS) form to the APCD. The Notice of Startup (NOS) form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. AIRS ID: 123/99AB Page 2 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO 5-11-060-TK25, TK28, TK33, and TK36 001 --- 0.45 --- Point 5-11-060-TK29 5-11-060-TK32 002 --- 0.24 --- Point E-01 003 1.9 0.02 3.7 Point Loadout 004 --- 3.62 --- Point Heater Treater, 005 14.3 45.6 23.9 Point F-1 & F-2 Fugitive 006 --- 3.5 --- Fugitive See "Notes to Permit Holder #4 for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site, or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Point 001: This emissions point shall be configured with a flare. The flare shall reduce the uncontrolled emissions of VOC to the emission levels listed in condition 6, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. Point 002: This emissions point shall be configured such that vapors are routed to a flare. The flare shall reduce uncontrolled emissions of VOC to the emission levels listed in condition 6, above. Operating parameters of the control equipment are identified in AIRS ID: 123/99AB Page 3 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 the Operating and Maintenance Requirement section of this permit. (Reference: Regulation No.3, Part B, Section III.E.) 9. Point 003: This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio controller. The NSCR shall be capable of reducing uncontrolled emissions of NOx, CO, and VOC from the unit to the emission levels listed in Condition 6, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 10. Points 005: The flare shall reduce emissions of VOC to the emission levels listed in condition 6, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Point 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point 5-11-060- TK25, TK28, 001 Condensate throughput 36,500 BBL/yr TK33, and TK36 5-11-060-TK29 002 Produced water throughput 36,500 BBL/yr 5-11-060-TK32 E-01 003 Consumption of natural gas as fuel 4.5 MMSCF/yr Loadout 004 Condensate and produced water 73,000 BBL/yr loading Heater Treater, F-1 & 005 Natural gas flaring 73 MMSCF/yr F-2 Compliance with the yearly consumption limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly AIRS ID: 123/99AB Page 4 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 consumption of natural gas and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable). 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. & 4.) 15. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. Point 001: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 18. Point 001: This source is subject to the recordkeeping, monitoring, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 19. Point 002: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance. This source shall meet the requirements to apply RACT and reduce emissions by installing and operating an MRW 25' flare stack (Reference: Regulation No. 3, Part B, III.D.2.a). 20. Point 004: This Condensate loading operation is subject to RACT requirements for new or modified minor sources located in ozone non-attainment areas. RACT requirements shall be met by complying with Condition 21 (Reference: Regulation 3, Part B, III.D.2) 21. Point 004: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 22. Point 006: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall AIRS ID: 123/99AB Page 5 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 apply Reasonably Available Control Technology for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). The owner or operator shall conduct Audio, Visual, and Olfactory inspections (AVOs) on a semi-annual basis. • Tag all leaking components with a date of leak detection, date of repair and rescreening. • Component leaks greater than 10,000 ppm shall be repaired as set forth below: o A first repair attempt shall be made within five days, with the leak repaired as soon as practicable, but no later than 15 days. Repaired components shall be re-screened within five days of repair to determine if the leak is repaired. If the rescreening shows a leak, then attempt another repair as soon as practicable, but no later than 15 days. Repeat the process until the rescreening shows no leak. o If a leak is detected but it is technically infeasible to make the repair without a process unit shutdown, repair of this equipment shall occur before the end of the next process unit shutdown. Records documenting the rationale shall be maintained, the component placed on the Delay of Repair list, the ID number recorded, and an estimated date for repairing the component included in the facility records. Monitoring to verify the repair must occur within 15 days after startup of the process unit. • The following records shall be maintained and kept onsite for two years and shall be made available to the Division upon request: o List of components screened and associated dates. o List of currently leaking components. o List of repaired components along with the repair method and associated repair dates. o List of successful repairs, repair delays, and post-repair screenings and associated dates. o Dates of monitoring equipment calibration. OPERATING & MAINTENANCE REQUIREMENTS 23. Points 001, 002, 003, 005, and 006: Upon startup of these points, the applicant shall follow the operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) AIRS ID: 123/99AB Page 6 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 24. Points 001, 002, and 005: The owner or operator shall demonstrate compliance with Condition 14, using EPA Method 9 to measure opacity from the flare. This measurement shall consist of a minimum twenty-four consecutive readings taken at fifteen second intervals over a six minute period. (Reference: Regulation No. 1, Section II.A.1 & 4) Periodic Testing Requirements 25. Point 003: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 26. Point 005: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the flare in order to verify the VOC content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. 27. Point 006: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ADDITIONAL REQUIREMENTS 28. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or AIRS ID: 123/99AB Page 7 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Point 003: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the permittee is exercising an alternative-operating scenario and is installing a permanent replacement engine. 29. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition, Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 30. MACT Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 31. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 32. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 33. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with AIRS ID: 123/99AB Page 8 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 34. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 35. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 36. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 37. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: (! Oluwaseun Ogungbenle Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit issued to Marathon Oil Company for a new synthetic minor E&P facility. AIRS ID: 123/99AB Page 9 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 Notes to Permit Holder: 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Pad II.E.1. of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/requlations/airregs/100102agcccommonprovisionsreq.pdf. 3) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (lb/yr) reportable? Rate (Ib/yr) Benzene 71432 A 198 Yes 10 Toluene 108883 C 160 No 8 Ethylbenzene 100414 C 18 No 1 001 Xylenes 1130207 C 59 No 3 n-Hexane 110543 C 870 No 44 2,2,4- 540841 C 61 No 3 Trimethylpentane Benzene 71432 A 204 Yes 10 002 n-Hexane 110543 C 642 No 32 Formaldehyde 5000 A 139 Yes 0 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 003 1,3-Butadiene 106990 A 4 No 4 Acrolein 107028 A 15 No 15 Toluene 108883 C 3 No 3 Benzene 71432 A 9 No 9 Benzene 71432 A 77 Yes 77 Toluene 108883 C 63 No 63 004 Ethylbenzene 100414 C 6 No 6 Xylenes 1130207 C 22 No 22 AIRS ID: 123/99AB Page 10 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 n-Hexane 110543 C 339 No 339 2'2,4 540841 C 23 No 23 Trimethylpentane Benzene 71432 A 6704 Yes 335 Toluene 108883 C 5045 Yes 252 Ethylbenzene 100414 C 717 No 36 005 Xylenes 1130207 C 1798 Yes 90 n-Hexane 110543 C 41530 Yes 2077 2,2,4- 540841 C 35 No 2 Trimethylpentane Benzene 71432 A 58 Yes 58 Toluene 108883 C 128 No 128 006 Ethylbenzene 100414 C 38 No 38 Xylenes 1130207 C 149 No 149 n-Hexane 110543 C 246 No 246 4) The emission levels contained in this permit are based on the following emission factors: Points 001: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source VOC 0.4882 lb/bbl 0.0244 lb/bbl E&P Tanks 71432 Benzene 0.0065 lb/bbl 0.00033 lb/bbl E&P Tanks 108883 Toluene 0.0053 lb/bbl 0.00026 lb/bbl E&P Tanks 100414 Ethylbenzene 0.00058 lb/bbl 0.00003 lb/bbl E&P Tanks 1330207 Xylenes 0.00008 lb/bbl 0.000004 lb/bbl E&P Tanks 110543 n-Hexane 0.0286 lb/bbl 0.0014 lb/bbl E&P Tanks 540841 2,2,4-TMP 0.002 lb/bbl 0.0001 lb/bbl E&P Tanks Note: The controlled emissions factors for point 001 are based on a flare control efficiency of 95%. These emission factors were developed using a pressurized liquids analysis from the Tsubaki Hills 08-62-34-4H well head. Point 002: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 State default factors 110543 n-Hexane 0.022 0.0011 State default factors 71432 Benzene 0.007 0.00035 State default factors Note: The controlled emissions factors for point 002 are based on a combustor control efficiency of 95%. AIRS ID: 123/99AB Page 11 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 Point 003: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.905 14.7 0.636 2.4 CO 1.541 5.8 1.276 4.8 VOC 0.011 0.04 0.005 0.02 5000 Formaldehyde 0.024 0.09 0.000024 0.00009 67561 Methanol 0.0031 0.0130 0.0031 0.0130 75070 Acetaldehyde 0.0028 0.0119 0.0007 0.0029 106990 1,3-Butadiene 0.0007 0.0028 0.0007 0.0028 107028 Acrolein 0.0026 0.0112 0.0006 0.0027 108883 Toluene 0.0006 0.0024 0.0006 0.0024 71432 Benzene 0.0016 0.0067 0.0004 0.0016 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8300 Btu/hp-hr, a site-rated horsepower value of 68, and a fuel heat value of 1300 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Data Manufacturer Data CO Manufacturer Data Manufacturer Data VOC Manufacturer Data Manufacturer Data 5000 Formaldehyde Manufacturer Data Manufacturer Data 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); AP42, Tab. 3.2-3 Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); AP42, Tab. 3.2-3 Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); AP42, Tab. 3.2-3 Natural Gas Point 004: Emission Factors - Uncontrolled CAS Pollutant lb/BBL Source loaded VOC 0.10 AP-42 71432 Benzene 0.0013 Engineering Calc. 108883 Toluene 0.0011 Engineering Calc 100414 Ethylbenzene 0.0001 Engineering Calc 1130207 Xylenes 0.0004 Engineering Calc 110543 n-Hexane 0.0058 Engineering Calc The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) =4.5 psia M (vapor molecular weight) = 36.45 Ib/Ib-mol T (temperature of liquid loaded) = 520 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. AIRS ID: 123/99AB Page 12 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 Point 005: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled NOx --- 0.3 lb/MMBtu 0.3 lb/MMBtu Manufacturer CO --- 0.5 lb/MMBtu 0.5 lb/MMBtu Manufacturer VOC 37.68 25005.5 1250.28 Engineering Ib/MMscf lb/MMscf Calculation 71432 Benzene 0.17 114.795 5.74 lb/MMscf Engineering Ib/MMscf Calculation 108883 Toluene 0.13 86.3971b/MMscf 4.32 lb/MMscf Engineering Calculation 100414 Ethylbenzene 0.02 12.2741b/MMscf 0.614 lb/MMscf Engineering Calculation 1330207 Xylenes 0.05 30.7951b/MMscf 1.54 lb/MMscf Engineering Calculation 711.137 Engineering 110543 n-Hexane 1.07 lb/MMscf 35.56 lb/MMscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the analysis of a gas sample collected from the Tsubaki Hills 08-62-34-4H well. The controlled VOC and HAP emissions factors for point 005 are based on the flare control efficiency of 95%. Point 006: Water/Oil Component Gas Service Heavy Oil Light Oil Service Service Connectors 28 --- 84 5 Flanges 24 --- 40 6 Open-Ended Lines 0 --- 1 0 Pump Seals 0 --- 2 0 Valves 19 21 2 Other 11 --- 15 6 VOC Content(wt%) 37.68% 93.91% 63.18% Benzene Content(wt%) 0.17% --- 0.9% 0.84% Toluene Content (wt%) 0.13% --- 2.71% 0.68% Ethylbenzene (wt%) 0.02% --- 0.86% 0.07% Xylenes Content(wt%) 0.05% --- 3.46% 0.24% n-Hexane Content (wt%) 1.07% --- 3.49% 3.7% *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents AIRS ID: 123/99AB Page 13 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. 5) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the'date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 6) Point 003: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source VOC, n-Hexane, Total HAPs PSD True Minor Source NANSR Synthetic Minor Source VOC MACT 7777 Major Source Requirements: Not Applicable Area Source Requirements: New Area Source 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecf r.q poaccess.q ov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK AIRS ID: 123/99AB Page 14 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ— Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ— Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 9) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilgaspermittino.html AIRS ID: 123/99AB Page 15 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 1, 2011 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the permittee shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The permittee shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the permittee shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The permittee may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/99AB Page 16 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 2.1.2 The permittee may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide (NOx) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer). Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. AIRS ID: 123/99AB Page 17 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOx and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOx are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOx and SO2, as precursors to PM10, if the potential to emit of NOx or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas-fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOx: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM1o: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/99AB Page 18 of 20 Marathon Oil Company Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500≤Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/99AB Page 19 of 20 Marathon Oil Company . Colorado Department of Public Health and Environment Permit No. 12WE2205 Air Pollution Control Division Issuance 1 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not"routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/99AB Page 20 of 20 Hello