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Home My WebLink About20122833.tiff STATE OF COLORADO John W.Hickenlooper,Governor Christopher E. Urbina, MD, MPH .0?•cotoR Executive Director and Chief Medical Officer Fe Dedicated to protecting and improving the health and environment of the people of Colorado . ,r0,‘**sr 4300 Cherry Creek Dr.S. Laboratory Services Division �"r87 " Denver,Colorado 80246-1530 8100 Lowry Blvd. RECEIVED Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 2012 of Public Health http://www.cdphe.state.co.us OCT 0 5 and Environment WELD COUNTY October 2, 2012 COMMISSIONERS Mr. Steve Moreno Weld County Clerk 1402 N 17th 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 October 6, 2012, 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 /1" �n�U 2012-2833 -EXA/O/i0/4904R /n-- 5--/v7 STATE OF COLORADC John W.Hickenlooper, Governor Christopher E.Urbina,MD, MPH /��A o�� Executive Director and Chief Medical Officer ti/T' � To 0 Dedicated to protecting and improving the health and environment of the people of Colorado Ler* 0, „ 4300 Cherry Creek Dr. S. Laboratory Services Division \\\r e"`vvv7"" Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health http://www.cdphe.state.co.us and Environment Website Title: Marathon Oil Company. —Pawnee Creek 9-57-18-114—Weld County Released to: The Greeley Tribune on October 2, 2012, published on October 6, 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 gas exploration facility in Weld County. The facility has the potential to emit (PTE) of 268.8 tons of Volatile Organic Compounds (VOCs) per year. The draft permit has limitations that will reduce emissions to 23.1 tons per year of VOCs. Since this source has the potential to emit greater than 100 tons per year of VOCs, but is willing to accept limits to bring the emissions below 100 tons per year, this source is considered to be a synthetic minor source for VOCs as such, this permit is subject to public comment per Regulation 3, Part B, Section Ill.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: Michael Cleary, EI Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B 1 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.co lorado.gov/cs/Satel I ite/CDPH E-A P/C BON/1 25 1 596498449 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Marathon Oil Company Permit Number: 12WE1546 Source Name PC 9-57-18-11H Source Location: Weld County: SWSW Section 18,T9N, R57W Point 001: Four(4)400 BBL fixed roof condensate storage tanks Point 002: Two (2) 400 BBL fixed roof Produced Water Storage Tank Point 003: One (1) reciprocating internal combustion engine Equipment Description: Point 004: One (1) Truck Loadout Operation Point 005: Enclosed Flare Point 006: Fugitive emissions from valves, flanges, connectors, and other components AIRS ID: 123/9810 Date: July 18, 2012 Review Engineer Michael Cleary Control Engineer: Chris Laplante Section 2-Action Completed X CP1 Modification APEN Required/Permit Exempt Final Approval Transfer of Ownership APEN Exempt/Permit Exempt 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? Yes X No Did the applicant submit all required paperwork? Yes X 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 Flash emission estimates were not Information Request letter to the source? included for produced water. The flare APEN did not include all NCRPs. On what date was this application complete? September 7, 2012 Section 4—Source Description AIRS Point Equipment Description Four(4)400 BBL fixed roof condensate storage tanks. Emissions from these tanks are 001 controlled by an enclosed flare. Two (2)400 BBL fixed roof Produced Water Storage Tank 002 Emissions from these tanks are controlled by an enclosed flare. One (1) Arrow, Model A-62, Serial Number 6B116001112, natural gas-fired, naturally 003 aspirated, 4SRB reciprocating internal combustion engine, site rated at 68 horsepower at 1800 RPM. This engine is equipped with a catalyst. Engine used to drive the pump jack. Page 1 004 Truck loadout of condensate. Associated gas emitted from the 3-phase separator and heater treater. Pending the 005 completion of pipeline infrastructure at this facility, emissions are routed to a flare. The flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 006 Fugitive emissions from valves, flanges, connectors, and other components 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? PMio CO 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) Is this source located at an oil and gas exploration site? X Yes No If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate (hydrocarbons that have Yes X No an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Is this source located at a facility that is considered a major source of hazardous air pollutant(HAP) Yes X No emissions Will this equipment be operated in any NAAQS X Yes No nonattainment area? Does this source load gasoline into transport vehicles?. Yes X No Section 5— Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific emission factors determined using gas sample and E&P Tanks. 002 CDPHE Condensate Storage Tank Emission Factors; CDPHE Memo 09-02 003 Manufacturer's data/AP-42 Table 3.2-1 AP-42: Chapter 5.2, Equation 1 L = 12.46*S*P*M/T 004 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] Maximum gas vented to atmosphere along with VOC weight fraction was used to 005 determine a site-specific emission factor.Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. 006 EPA-453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? I X Yes No Basis for Potential to Emit (PTE) AIRS Point Process Consumption/Throughput/Production Page 2 001 26,280 BBL condensate per year(21,900 x 1.2) 002 153,300 BBL per year(127,750 x 1.2) produced water • 003 4.85 MMscf natural gas fuel consumed 004 149,650 BBL per year condensate/produced water loaded 005 21.90 MMscf produced gas per year 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 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 21,900 BBL condensate per year Does this source use a control device? X Yes No 002 127,750 BBL per year wastewater Does this source use a control device? X Yes X No 003 4.85 MMscf natural gas fuel consumed Does this source use a control device? Yes X No 004 149,650 BBL per year condensate/produced water loaded Does this source use a control device? X Yes No 005 21.90 MMscf produced gas per year Does this source use a control device? X Yes No 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 a control device? Yes X No % Reduction AIRS Point Process Control Device Description Granted 001 01 Enclosed combustor 95 002 01 Enclosed combustor 95 VOC: 50.0% 003 01 Catalyst NOx: 83.7% CO: 17.2% 004 01 None --- 005 01 Enclosed combustor 95 006 01 None -- Page 3 Section 6-- Emission Summary(tons per year) Point NO„ VOC CO Single HAP Total HAP 001 7.97 --- -- 002 16.7 1.69 (n-Hexane) 2.23 003 11.36 0.03 4.48 0.07 0.11 PTE: (formaldehyde) 004 10.2 0.85 (n-Hexane) 0.98 005 3.96 249 6.60 5.84 (n-Hexane) 7.36 006 3.50 0.03 (Benzene) 0.03 Total PTE emissions: 15.32 287.4 11.08 8.48 (n-Hexane) 10.7 001 6.64 --- 002 16.7 1.41 (n-Hexane) 1.86 003 11.36 0.03 4.48 0.07 0.11 Uncontrolled point (formaldehyde) source emission rate: 004 10.2 0.85 (n-Hexane) 0.98 005 3.96 249 6.60 5.84 (n-Hexane) 7.36 006 3.50 0.03 (Benzene) 0.03 001 0.33 _- --- 002 0.84 --- ---• 003 1.85 0.02 3.71 0.07 0.11 Controlled point (formaldehyde) source emission rate: • 004 10.2 0.85 (n-Hexane) 0.98 005 3.96 12.5 6.60 0.29(n-Hexane) 0.37 006 3.50 0.03 (Benzene) 0.03 Total APEN Reported 5.75 27.4 10.31 1.35(n-Hexane) 2.11 emissions: Section 7- Non-Criteria/Hazardous Air Pollutants Uncontrolled Emission Are the Controlled Pollutant CAS # BIN Rate emissions Emission Rate reportable? (Ib/yr) (Ib/yr) — Benzene 71432 A 168 Yes 8 001 n-Hexane 110543 C 1108 Yes 55 Benzene 71432 A 894 Yes 45 002 n-Hexane 110543 C 2820 Yes 141 Benzene 71432 A 23 No NA Toluene 108883 C 3 No NA 1,3-Butadiene 106990 A 4 No NA 003 Formaldehyde 50000 A 139 Yes 0 Acetaldehyde 75070 A 16 No NA Acrolein 107028 A 15 No NA Methanol 67561 C 18 No NA J Page 4 Benzene 71432 A 257 Yes NA n-Hexane 110543 C 1698 Yes NA 004 Toulene 108883 C 168 No NA Xylenes 1130207 C 48 No NA Benzene 71432 A 1600 Yes 80 Toluene 108883 C 1425 Yes 71 005 Ethylbenzene 100414 C 270 No 13 Xylenes 1130207 C 576 No 29 n-Hexane 110543 C 11668 Yes 584 Benzene 71432 A 58 Yes NA Toluene 108883 C 109 No NA 006 Ethylbenzene 100414 C 53 No NA Xylenes 1130207 C 414 No NA n-Hexane 110543 C 358 No NA Note: Regulation 3, Part A, Section ll.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 X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method VOC, Liquids Analyses 001 01 HAPS PS Memo 05-01 according to PS Memo 05-01 002 None 003 None 004 None VOC, Site-specific gas 005 01 HAPS State only requirement analysis VOC Hard component 006 01 RAPS State only requirement count Section 9 —Source Classification Is this a new previously un-permitted source? X Yes No Point 001: X True Synthetic Major Minor Minor True Synthetic Major Point 002: X Minor Minor Synthetic True What is this point classification? Point 003: X Minor Major Minor Point 004 X True Synthetic Major Minor Minor Point 005: True Synthetic X Major Minor Minor Page 5 Point 006: X True Synthetic Minor Minor Major What is this facility classification? True X Synthetic Minor Minor Major Classification relates to what programs? X Title V PSD X NA NSR 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 and n-Hexane 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 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 Air Quality Standards (NAAQS)? Yes X No If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Re ulation 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. Regulation 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. Regulation 3-APENs Construction Permits, Operating Permits PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in an non-attainment area with uncontrolled actual emissions 001-006 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 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 ll.D.3.a) Page 6 Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance 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 began service after the date above, this source is considered "new or modified." Operator is using 0.6 saturation factor(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 Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No WHY? Each storage vessel has a storage capacity of less than 471 barrels 002 None NSPS JJJJ: Manufactured after the applicable date (7/1/2008 for<100Hp), this non-emergency SI 003 engine is subject to control requirements under this section. It must meet emission levels in 40 CFR 1048 101 (c) 004 No applicable subpart. This facilit is not a bulk gasoline terminal. 005 None 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 WHY? This site is not engaged in the extraction of natural gas liquids from field gas, fractionation of mixed natural gas liquids Regulation 7-Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks 001 since it is located in an non-attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of VOC.) 002 None 003 None No sections apply. This facility is neither a terminal, nor a bulk plant per definitions in Reg 004 7, Section VI.C. 005 None 006 Section XII.G: Facility is not a natural gas processing plant located in non- attainment area and,thus, is not subject to Section XII.G. Regulation 8— Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution • This source is not subject to MACT EEEE because it is not located at a major 001 source of HAP. MACT HH • This source is not subject to MACT HH because it is not located at a major source of HAP. 002 None 003 MACT 7777: As a "new" engine at an area source,this engine is subject to this subpart. It shall satisfy this requirement by meeting the requirements of NSPS JJJJ MACT EEEE: 004 Not subject because minor source of HAPs Page 7 005 None MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators and fugitives), then fugitive emissions are subject to MACT HH. 006 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? This is an area source and there is no dehydrator located at this facility Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (Y/N) Emission Factor Source (%) 14.003 E&P TanksNasquez lb/1000 gal V0C No 95 throughput Beggs 0.1826 E&P Condensate Benzene/ E&P TanksNasquez 001 01 Storage Tanks 16/1000 gal 71432 N°95 throughput Beggs 1.2046 n-Hexane/ E&P TanksNasquez 1b/1000 gal 110543 No 95 throughput Beggs SCC 40400311 —Fixed Roof Tank, Condensate, working+breathing+flashing losses Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (Y/N) Emission Factor Source (%) 6.2381 lb/1000 V0C No CDPHE PS Memo 09 95 gallons throughput 0.1667 01 Produced Water lb/1000 002 Storage Tanks gallons Benzene No CDPHE PS Memo 09 95 • throughput 0.5238 lb/1000 n-Hexane No CDPHE PS Memo 09 95 gallons throughput SCC 40400315— Fixed Roof Tank, Produced Water, working+breathing+flashing losses Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (Y/N) Emission Factor Source (%) 0.04 V0C No Manufacturer 50 Reciprocating g/bhp-hr 01 internal 14.7 N0x No Manufacturer 83.7 003 combustion g/bhp-hr engine 5.80 q/bhp-hr CO No Manufacturer 17.2 SCC 20200253: Internal combustion Engines (Natural Gas, 4cyl/Rich Burn) Process Process/ Emission Pollutant/ Fugitive Emission Point Process Description throughput 9 Factor Control p Limit Factor CAS# (Y/N) (%) Source 3.26 lb/1,000 V0C No AP-42 0 gallon throughput 8.38e-02 004 01 Truck Loadout 73,000 lb/1,000 V0C BBL/yr gallon Benzene No Wt.Fraction 0 throughput 5.54e-02 lb/1,000 V0C n-Hexane No 0 gallon Wt.Fraction throughput Page 8 SCC 40600132: Crude Oil: Submerged Loading (Normal Service) Use if S = 0.6 Fugiti Process • Emission Pollutant/ Control Point Process Description Factor CAS# (ve YEN) Emission Factor Source (%) 22759.32 VOC No VOC Wt Fraction 95 lb/MMscf 359.82 NOx No AP-42 0 lb/MMscf 600.00 CO No AP-42 0 lb/MMscf 73.0574 Benzene No Engineering Calculation 95 01 Venting lb/MMscf 005 65.0585 Toluene No Engineering Calculation 95 lb/MMscf 12.3063 Ethylbenzene No Engineering Calculation 95 lb/MMscf 26.2908 Xylenes No Engineering Calculation 95 lb/MMscf 533.702 n-hexane No Engineering Calculation 95 lb/MMscf SCC 31000215: Flares Combusting Gases >1000 BTU/scf Fugiti Point Process Process Pollutant/ ve Emission Factor Source Control Description CAS# (�,/N) (%) 01 Fugitive VOC VOC Yes EPA-453/R-95-017,Table NA 006 Leak Emissions 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14— Miscellaneous Application Notes General APENs were submitted for a facility wide permit for a new synthetic minor, E&P site located in Weld County. This source will need to go to public comment. (e,VOC emissions >25tpy) 8/22/2012 A draft copy of the permit was sent to Scott Park of Marathon Oil on and he was given until 8/22/2012 to comment. The operators process description provide, indicates two flares. Marathon representative, Scott Park, later clarified one to be a back-up. The flare identified as Pt. 005 is reportedly also the flare used to control the tank emissions as the flow diagram provided would seem to support. For this reason, no O&M plan specifically referring to Pt. 005 was provided as the operator felt it would be redundant. O&M information entered in CACTIS will reflect this and it will be noted that flare (point 005) will also be covered. Page 9 • Section 14—Miscellaneous Application Notes AIRS Point 001 Condensate Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2.0 TPY (permit threshold). Emissions were estimated using E&P Tanks and Vasquez Beggs with an extended natural gas liquid analysis of the oil dated 3/13/2012. The representative oil sample from this site shows a vapor pressure of 9.84 psia. The operator stated that because this is less than the ambient pressure at this location, E&P Tanks modeling results in no flash emissions. To account for this, the Vasquez-Beggs Solution was used to estimate the VOC flash emissions. To estimate HAP emissions, the speciation was then based on the composition projected from the E&P Tanks output. The working and breathing losses were determined by modeling one (of four) tanks with %of the total throughput. The resulting values were then multiplied by four. Site-specific emission factors were back-calculated based on the resulting output estimates. VOC = (4.60+1.84 TPY*2000 Ibi) /(21,900 bbl/yr)/ (42 gal/bbl)*1000ga1 = 14.003 lb/1000gal Benzene = (48+120 Ibs/yr)/(21,900 bbl/yr)/(42 gal/bbl)*1000gal = 0.1826 lb/1000gal n-Hexane = (312+796 Ibs/yr) /(21,900 bbl/yr)/(42 gal/bbl)*1000gal = 1.2046 lb/1000gal This source is located in the 8-hour ozone non-attainment area (this portion of Weld County is in non- attainment). Therefore, the provisions of Regulation 7, Section XII apply to this source. The statewide requirements of Regulation 7, Section XVII.C do not currently apply to this source since actual uncontrolled emissions are less than 20 tpy. 9/10/2012 Carissa questioned the validity of the oil sample used and, with that, the use of the Vasquez Beggs method. When contacted Scott Park, of Marathon Oil, expressed confidence in the sample indicating that he collected the sample himself. He also indicated that Marathon has encountered a few wells producing product with uncommonly low vapor pressure. Given the unusual characteristics of this well product, further testing requirements may be included in the permit. Page 10 AIRS Point 002 Produced Water Storage Tanks Page 11 A permit will be issued because the facility-wide uncontrolled VOC emissions are greater than 5.0 TPY (permit threshold). The emission estimates provided by the applicant for these produced water tanks are based on E&P Tanks and an extended natural gas liquid analysis of the oil dated 3/13/2012. The Division considers this approach reasonable since the oil layer will sit on top of the mixture and provide the most significant source of VOC/HAP emissions. Marathon Oil is requesting a total facility-wide produced water throughput of 127,750 bbls/yr., which is the throughput basis for estimating emissions. These tanks operate parallel, so emissions are based on the tanks model run with the 1/2 of the total amount of water processed in each tank. The amount per tank used in the model was then 63,875 bbl/yr (175 bbl/day). The emission estimates from E&P Tanks were then multiplied by 2 to estimate the emission from both tanks. Site-specific emission factors were back-calculated based on the resulting output estimates. VOC = (1.266 TPY*2000 lb/T)/(127,750 bbl/yr)/(42 gal/bbl)*1000gal = 0.4719 lb/1000gal Benzene = (32 Ibs/yr)/(127,750 bbl/yr)/ (42 gal/bbl)*1000gal = 0.05964 lb/1000gal n-Hexane = (208 lbs/yr) /(127,750bb1/yr)/(42 gal/bbl)*1000gal = 0.03877 lb/1000gal 9/10/2012: Initially, the operator assumed the produced water would not flash and, therefore, estimates did not include any projected flashing losses. Scott Park initially rejected the idea of using the state emission factors when presented and subsequently emailed estimates derived from the Vasquez-Beggs using the condensate characteristics. The Division considers this approach reasonable since the condensate layer will sit on top of the mixture and provide the most significant source of VOC/HAP emissions. The Vasquez-Beggs Solution was used to estimate the VOC flash emissions and then HAP emissions were based on the composition projected from the E&P Tanks output. (as was done with the condensate tank emissions). However, I noted that this method seemed to be overestimating emissions and I encouraged, Mr. Park to use the preferred method. (state-developed factors for produced water) and he agreed. 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 Garfield, Mesa, Rio Blanco and Moffat 0.178 0.004 0.010 Remainder of Colorado 0.262 0.007 0.022 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 Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 This source is located in the 8-hour ozone non-attainment area E&P Tanks + Vasquez-Beggs method resulted in the follow: VOC: 1.27 TPY+ 27.98 TPY = 29.25 TPY Benzene: 32 lbs/yr+701 lbs/yr= 733 lbs/yr or 0.367 tons/yr nHexane: 2081bs/yr+4645 lbs/yr = 48531bs/yr or 2.426 tons/yr State emission factors result in the following: VOC: 127,750 bbl/year x 0.262 lbs/bbl x 1 ton/2000lbs = 16.7 tons VOC/yr Benzene: 127,750 bbl/year x 0.007 lbs/bbl x 1 ton/2000lbs = 0.447 tons/yr nHexane: 127,750 bbl/year x 0.022 lbs/bbl x 1 ton/2000lbs = 1.41 tons/yr Page 12 AIRS Point 003 Reciprocating internal combustion engine A permit will be issued because the uncontrolled NOx emissions are each greater than 2.0 TPY (permit threshold). According to manufacturer specifications, the post control emission factors for NOx and CO are based on EPA regulation limits for engines <100Hp manufactured after 7/1/2008 ( 2.40 g/hp-hr NOx and 4.8 g/hp- hr CO). AIRS Point 004 Truck Loadout Units Basis S 0.6 Submerged loading: dedicated normal service based on source's description/drawings P 4.5 Psia AP-42 Table 7.1-2 M 50.78 Lb/lb-mole Based on EPA TANKs run T 524.67 Deg R Based on source's knowledge of bulk liquid temperature L 3.26 Lb/10^ gal This value is used to calculate annual emissions 0.137 Lb/bbl 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 50.78 lb/lb-mole T 524.67 deg. R L 3.261b/10^3 gal 1.37e-01 lb/bbl Annual requested Throughput 6285300ga1/yr Annual requested VOC emissions 204651b/yr 10.23tpy The operator has chosen to designate the emissions resulting from the loadout of both the condensate and produced water as one (1) emission point. It is assumed that the top layer of produced water will be condensate/oil and, thus, loading losses would be estimated in the same manner. Therefore, the calculations above reflect the total throughput of both loadout sources combined (149,650 bbl/yr). Page 13 AIRS Point 005 Produced gas A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (permit threshold). The emissions were based off of an extended gas analysis that was dated 3/13/2012. An initial extended gas analysis will not be required because the extended gas analysis provided was performed within a year of this submittal. Emissions were calculated using VOC wt fraction. Flowrate MW mass fraction (scf/hr) * (Ib/Ib-mol) *(% fraction from sales gas analysis) /(379.6 scf/lb-mol) = lb/hr* (hr/yr)/2000 lb/T) = TPY VOC = (249.2 TPY *2000 Ib/T) /(21.9 mmscf/yr) =22759.4 lb/MMscf Benzene = (1600 Ib/yr)/21.9 mmscf/yr= 73.057 lb/mmscf Toluene = (1425 Ib/yr) /21.9 mmscf/yr= 65.058 lb/mmscf Ethylbenzene = (270 Ib/yr)/21.9 mmscf/yr= 12.306 lb/mmscf Xylenes= (576 Ib/yr) /21.9 mmscf/yr= 26.291 lb/mmscf n-Hexane = (11688 Ib/yr)/21.9 mmscf/yr= 533.70 lb/mmscf NOx and CO emissions estimates are based on calculations for the combustion of tank vapors in addition to produced gas. The operators process description provided states the presence of two flares. Marathon representative, Scott Park, later clarified one to be used as a back-up. The flare identified as Pt. 005 is reportedly used to control the tank emissions as well as the separator emissions, as the flow diagram provided would • seem to support. • Therefore, the flare will be subject to the more stringent, zero emissions, requirements. • For this reason, no O&M plan specifically referring to Pt. 005 was provided as the operator felt it would be redundant. AIRS Point 006 Fugitive VOC Leak Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (permit threshold). Requested emission limits appear to include a 'factor of safety' such that annual levels calculated according to EPA-453/R-95-017, Table 2-4 were rounded up to the next 1/101h of a ton. The emissions were based off of an extended gas analysis that was dated 3/13/2012. An initial extended gas analysis will not be required because the extended gas analysis provided was performed within a year of this submittal. Fugitive calculations included with the original package appeared to contain an error. I spoke to Marsha Sonderfan, of Golder Associates, on 7/23/2012 at which point she indicated that she would resubmit the calculations and APEN. Having not heard from her or received anything, I emailed Scott Park of Marathon oil. He forwarded the information from her on 8/20/2012. Page 14 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY- \ 1 Current Status(Check all that apply) 12319310 I pal Reason for APEN Submittal((Check all that apply) / /q\CFj` \� AIRS ID#1: ❑ APEN update only s ��2� ® New or previously unreported battery ❑ Modification to existing source ^-,=.� ?o 2 D Previously grandfathered battery' ❑ Registration for coverage under general permit n GP0'101:- ❑ Synthetic minor facility &cancellation request for individual permits: ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit. ❑ Registered under general permit no.GPO] ❑ Administrative permit amendment' ❑ Permitted under individual permit: 12.WEI54 6 ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division , ®To review a draft of the permit prior to issuance Company Name9: Marathon Oil Company OGCC Operator#: 53650 Mailing Address1s': 4557 Denrose Court spark@marathonoil.co City: Fort Collins State: CO Zip: 80524 E-mail: m Contact Name: Scott Park Phone: (970)419-7809 Fax: Tank Battery Namel l: PC-9-57-18-1H Number of tanks: 4 Location'(QQ Sec.Twp. Range.): SWSW 518 T9N R57W County: Weld Total tank capacity[bbl]: 1600 bbl Calendar year for which"Actual"data applies'3: Projected Year(s)tank(s)were placed in service'(: Control Description's: MRW Technologies Flare Control Efficiency's: 95% Condensate Throughput"[bbl/year] Requested'8: 21,900 Maximum for PTE calculation19: 21,900 Actual2s: 17,520 While Controls Operational" 17,520 Other equipment at facility22: Produced Water Storage Tanks,Truck Loadout,Fugitives,Pump Driver Engine,Heater Treater Comments: Condensate throughputs are maximum projected. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑ Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery,"hvZ/fir Requested Emissions18 Actual Emissions20 Pollutant" [Ib/bbl] PTE25'- trio Uncontrolled's Controlled27 Uncontrolled's Controlled27 , VOC[tons/year] N/A 7 9T 6.64 0.33 5.60 0.28 NOx[tons/year] CO[tons/year] Benzene[lbs/year] N/A 2162 168 8.4 144 7.2 n-Hexane[lbs/year] N/A /33o 1108 55.4 933 46.7 i Wells serviced by this tank or tank battery28, API#: 05-123-33752 Name: Pawnee Creek 9-57-18-1H ®Newly Reported Well API#: Name: C r A r r 11 ❑Newly Reported Well 4o=$.,/-* tx h '. -- 21#: Name: ❑Newly Reported Well Newly Reported Well N P1/1: Name: 111:11 _ rI, __ ❑ Rep co ' .PI#: Name El Newly Reported Well +`.. Xs m ,P1#: Name: p; ' r l4. "'. ❑Newly Reported Well H O 3I#: Name: [ i`"' '""I El Newly Reported Well 0 - 0 '—' he sig ore 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 ('°-[, b^a ry lot edge and belief. If this is a registration for coverage under general permit GPO I,I further certify that this source is and will be operated/1:j, oj i ful c liannceitith a h con i ion eneralpermit GP0I. 1 :cal. z Is A Y `�C ,4 ,_o-- `l� A°/Z - �t,: N U � ign ture of Legally Authorized Person(not a vendor or consultant) Date II ; N) 0 obert Nickola Operations Manager T. ype or Print Name of Person Signing Above Official Title --' ubmit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: o ling of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 �( \77 (303)692-3150 IlWV IJ 250 General Permit fee for each new GP 4300 Cherry Creek Drive South � 27018 t :gistration to: Denver,CO 80246-1530 ry ra 11a it 1nm 'tie I n___ , _en <Dric,...,,Anrn_sne__rPC,.,,A—sstsTanicAPPN Ann Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Notes and Instructions See PS Memo 05-01: Condensate Tank Guidance for further information on policies,APEN requirements,'definitions and emission calculations. 1 AIRS ID#:For previously reported sources,the AIRS ID number is the 10 digit point number found in the detail section of the Division's annual emission fee.invoice. For newly reported sources,leave blank so the Division may assign one. 2 Previously grandfathered:Batteries installed prior to 12/30/02 and not subsequently modified are grandfathered from minor source permitting. 8-hour Ozone Control Area:Adams,Arapahoe,Boulder,Broomfield,Denver,Douglas,lefferson,and portions of Larimer and Weld counties. 4 APEN Update Only :This notice is valid for five(5)years unless a significant change is made.A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. Modification to existing source:Modifications include but are not limited to well additions,tank installation or replacement,repiping,etc. 6 General Permit Registration: This APEN will be considered a cancellation request for an individual permit, if general permit coverage is selected for a battery. The individual permit will not be cancelled until the general permit registration is approved. Administrative Permit Amendment: This includes company name changes,transfer of ownership,and other changes defined in Regulation No. 3, Part A, Section I.B.I. You must also submit a general Permit Application form to document the administrative amendment. 9 Review Draft Request: Review requests will usually add to both processing time and costs. Any additional charges incurred by the Division in providing a draft and correspondence with the applicant will be billed to the applicant. The Division will consider the request an official extension of the processing deadlines specified by Regulation No.3,Part B,Section III. 9 Company Name:The name of the owner or operator of the condensate storage tank battery. 10 Mailing Address: This is the address to which correspondence, including permits and fee invoices, will be sent. If invoices are to be sent to a different address please attach a separate page with billing address(s). Tank Battery Name:A unique name for each tank battery. 12 Location:The legal STR(Section,Township,Range)location of the facility to the nearest Quarter-Quarter Section. 12 Calendar year for which "Actual" data applies: Emissions reported in this APEN will be used to calculate annual emission fees for this and all subsequent years until a revised APEN is filed. 14 Year(s)tank(s)were placed in service:The year that the battery was installed or placed in service. is Control Description:List any control equipment such as flares,VRUs,carbon canisters,or other capture devices,which reduce VOC emissions. 16 Control Efficiency: Enter the control efficiency(reflecting the combined destructton and capture efficiency)while controls are operational. 17 Condensate Throughput:The quantity of condensate transferred through this tank battery annually in units of barrels of condensate per year. 16 Requested: Requested throughput/ emission levels are used for individual permitting purposes and should include a reasonable margin above actual values. Use NM for requested throughput/emission values if the battery retains grandfathered status or if applying for GP coverage. 19 Maximum for PTE calculation: Multiply the greater of the highest rolling 12-month production total during the last five years or the projected throughput for the following I2-month period by a factor of 1.2. 20 Actual:Actual reporting levels should represent the best estimates of total annual condensate throughput and pollutant emissions for the specified data year. For the first year of operation, projected annual throughputs / emissions are acceptable. In subsequent years, actual data from the previous calendar year should be used. 21 While Controls Operational: The best estimates of actual condensate throughput while controls were installed and operational. If controls were operational for the entire calendar year, this value will be equal to the actual annual throughput. Otherwise, the throughput subjected to controls should be proportioned based on the dates the controls were operational. 22 Other equipment at facility:Enter the AIRs ID of other APEN reportable equipment at facility if assigned to a different AIRs facility ID. 23 Site-specific emission factors: Check this box if site specific emission factors are provided and used to estimate emissions. Attach supporting site-specific emission factor documentation. State EFs may be used only if uncontrolled emissions calculated with the state EFs are less than 80 tpy. 24 Pollutant: Estimated annual emissions of the specified criteria and non-criteria reportable pollutants (NCRP) emitted by this tank battery and associated control equipment. If values are left blank,the Division will estimate emissions based on the reported condensate throughputs. If NCRP other than those listed are emitted above reporting thresholds,attach a completed Non-Criteria Reportable APEN Addendum listing these emissions. 2''Potential to Emit(PTE):Estimated annual maximum potential tonnage of pollutant emitted by this tank or tank battery calculated by multiplying the "Maximum for PTE" throughput value by the appropriate emission factor. Note: This PTE value is for the battery only, the emissions from other equipment at the same stationary source should be considered when determining the PTE for the facility. 26 Uncontrolled:Estimated uncontrolled emissions from this tank battery based on the annual condensate throughput. 27 Controlled: Estimated controlled emissions from this tank battery. This value is calculated by applying the appropriate control efficiency to emissions generated from throughput "while controls operational". A control efficiency of zero should be used for emissions generated while no controls were operating. These two values are summed to obtain the annual controlled emissions. 28 Wells serviced-ty;this tank or tank battery: List all wells from which this tank battery receives condensate. Provide the well name and API number`as ttepo{ted to the Colorado Oil and Gas Commission. Check if this well has not previously been reported for this tank battery. __. Pane 9nf9 tort c,......nonr� �..� ..,... ... .__.-. . k. N 00 � I ae Y _ 1 L Gl N O E L e al 0. O V t. `v C. C P. O L E O10. ❑ en cii en E —C) 3,_ _ 0 W „et zu N N N 4. q? k. t W a O\ Q+ ON w ia o ° �c U Fy C 145 a `a7 v' c a .� y aof o ` 000 3 1+ co d e k C h rr}W .. "- > " c s� N 3 -C � e fl C q p j C w c .. R Cr.)'.3 k '� o ci y c _s 0,7 O0 w 0 �. ra i "^ W .. m e f' p E L R P L a o -" m E .�. h °4 W + `a 4 c cll y « a. 0 .o c. „, .. - a' _ 7 m vi E i o c o s F a c1/4Thv'^� a L v v v P. m C Y E m p N s s. 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O q g N €O) O o` a G✓y to a ^� E U I"I rl °per° W F .-7 _ W c r.g E 1 :nov a dm 'E2 v h y . c yd I -- w c 'a z . o d u g o c -rd - o E um c N c 5 'E' 'i o O ON o 3 3 C a s O. °' "' W C W c U N _ d v v E \ t z Lt Enu U w O o., Y O u o ®''.- w 4,.. op STATE OF COLORADO �/.eF��lO� COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT (;fie/ F AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 1876 CONSTRUCTION PERMIT • PERMIT NO: 12WE1546 Issuance 1 DATE ISSUED: ISSUED TO: Marathon Oil Company THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and Gas facility, known as the Pawnee Creek 9-57-18-1H, located at Section 18, Township 9 north, Range 57 west, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Description Point Four(4) 400 BBL fixed roof condensate storage tanks. 5-11-060-TK21 thru 24 001 Emissions from these tanks are controlled by an enclosed flare (F-1). Flare F-2 will serve as a back-up. Two (2) 400 BBL fixed roof Produced Water Storage Tank 5-11-060-TK19 & 20 002 Emissions from these tanks are controlled by an enclosed flare (F-1). Flare F-2 will serve as a back-up. One (1) Arrow, Model A-62, Serial Number 6611B001112, natural gas-fired, naturally aspirated, 4SRB reciprocating E-01 003 internal combustion engine, site rated at 68 horsepower at 1800 RPM. This engine is equipped with a catalyst. Engine used to drive the pump jack. Loadout 004 Truck loadout of condensate. Associated gas emitted from the separators and heater treater. Produced Gas Pending the completion of pipeline infrastructure at this facility, 005 emissions are routed to a flare. The flare has a minimum F-1 and F-2 combustion efficiency of 95%. The flare is enclosed. Flare F-2 will serve as a back-up. Fugitive 006 Fugitive emissions from valves, flanges, connectors, and other components Point 003: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow A-62 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: AIRS ID: 123/9810 Page 1 of 18 Condensate Tank Version 2009-1 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the APCD no later than fifteen days after issuance of this permit y 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, II.G.2). For 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. 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: AIRS Tons per Year Facility Equipment ID Point Emission Type NO,, VOC CO 5-11-060-TK21 thru 001 0.33 24 Point 5-11-060-TK19 & 20 002 0.84 Point E-01 003 1.85 --- 3.71 Point Loadout 004 10.2 Point Produced Gas 005 3.96 12.5 6.60 Point F-1 and F-2 AIRS ID: 123/9810 Page 2 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division Fugitive 006 3.50 Fugitive See "Notes to Permit Holder#4"for information on emission factors and methods used to calculate limits. Compliance with the annual limits 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 twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month 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 permitted emission units, requiring an APEN, at this facility. 7. 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. 8. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) AIRS Pollutants Facility Equipment ID Control Device Point Controlled 5-11-060-TK21 thru 24 001 Enclosed combustor VOC 5-11-060-TK19 & 20 002 Enclosed combustor VOC E-01 003 Catalyst NOx,CO, VOC Produced Gas VOC 005 Enclosed combustor F-1 and F-2 PROCESS LIMITATIONS AND RECORDS 9. These sources shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates 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 AIRS Annual Facility Equipment ID Point Process Parameter Limit 21,900 5-11-060-TK21 thru 24 001 Condensate throughput bbl/yr 127,750 5-11-060-TK19 & 20 002 Produced water throughput bbl/yr 4.85 E-01 003 Consumption of natural gas as a fuel MMscf/yr. AIRS ID: 123/9810 Page 3 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division Loadout 004 Condensate Loading 149,650 bbl/yr Produced Gas 21 9 005 Natural gas throughput F-1 and F-2 MMscf/yr Compliance with the annual throughput 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 throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND/OR FEDERAL REGULATORY REQUIREMENTS 10. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. 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. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 13. 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. 14. 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. 15. POINT 002, 005: 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 enclosed combustion device. (Reference: Regulation No. 3, Part B, III.D.2.a). 16. POINT 004: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology(RACT) requirements of Regulation Number 3, Part B, III.D.2.a.. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 17. POINT 001 & 006: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and AIRS ID: 123/9810 Page 4 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division handling operations, regardless of size, shall be designed,operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 18. 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 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 19. Points 001, 002, 003, 005, 006: Upon startup of these points, the owner or operator shall follow the most recent 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.). COMPLIANCE TESTING AND SAMPLING AIRS ID: 123/9810 Page 5 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division Initial Testing Requirements 20. Point 001: The owner or operator shall demonstrate compliance with Conditions 12 & 13, using EPA Method 22 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) 21. Point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site- specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 22. Point 006: Within one hundred and eighty days(180)after commencement of operation,the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 23. 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. 24. 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. 25. Point 006: On an annual basis, the permittee 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 26. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, ILO) 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 (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a AIRS ID: 123/9810 Page 6 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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 sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; 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 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. 27. 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). GENERAL TERMS AND CONDITIONS 28. 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 11.6 upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 29. 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. 30. 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 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. 31. 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. AIRS ID: 123/9810 Page 7 of 18 Marathon OH Company Colorado Department of Public Health and Environment Air Pollution Control Division 32. 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. 33. 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. 34. 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: r , 1 r i / Michael Cleary Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Issued to: Marathon Oil Company for a facility wide permit at a new, synthetic minor facility. AIRS ID: 123/9810 Page 8 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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 Part II.E.1 of the Common Provisions Regulation. See: http://www.cd phe.state.co.us/req u lations/airreq s/100102agcccommon provisionsreq.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 168 Yes 8 001 n-Hexane 110543 C 1108 Yes 55 Benzene 71432 A 894 Yes 45 002 n-Hexane 110543 C 2820 Yes 141 Benzene 71432 A 23 No NA Toluene 108883 C 3 No NA 1,3-Butadiene 106990 A 4 No NA 003 Formaldehyde 50000 A 139 Yes 0 Acetaldehyde 75070 A 16 No NA Acrolein 107028 A 15 No NA Methanol 67561 C 18 No NA Benzene 71432 A 257 No NA n-Hexane 110543 C 1698 Yes NA 004 Toulene 108883 C 168 No NA Xylenes 1130207 C 48 No NA Benzene 71432 A 1600 Yes 80 Toluene 108883 C 1425 Yes 71 005 Ethylbenzene 100414 C 270 No 13 Xylenes 1130207 C 576 No 29 n-Hexane 110543 C 11668 Yes 584 006 Benzene 71432 A 58 Yes NA AIRS ID: 123/9810 Page 9 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division Toluene 108883 C 109 No NA Ethylbenzene 100414 C 53 No NA Xylenes 1130207 C 414 No NA n-Hexane 110543 C 358 No NA 4) The emission levels contained in this permit are based on the following emission factors: POINT 001: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/1000gal lb/1000 gal Source Condensate Condensate Throughput Throughput VOC 14.003 0.7002 E&P Tanks/Vasquez Beggs 71432 Benzene 0.1826 9.13e-03 E&P Tanks/Vasquez Beggs . 110543 n-Hexane 1.2046 6.023e-02 E&P Tanks/Vasquez Begs Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. POINT 002: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/1000 gal. lb/1000 gal. Source Produced Water Produced Water Throughput Throughput VOC 6.2381 3.119e-01 CDPHE PS Memo 09 71432 Benzene 0.1667 8.335e-03 CDPHE PS Memo 09 110543 n-Hexane 0.5238 2.619e-02 CDPHE PS Memo 09 Note: The controlled emissions factors for point 002 are based on the flare control efficiency of 95%. Point 003: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source gal/bhp-hr gal/bhp-hr VOC 0.04 0.02 Manufacturer _ NOX 14.7 2.40 Manufacturer CO 5.80 4.80 . Manufacturer 50000 HCHO 0.09 0.00 Manufacturer POINT 004: Emission Factors Uncontrolled CAS Pollutant lb/BBL Source loaded VOC 1.37e-01 AP-42 71432 Benzene _1.135e-02 AP-42 AIRS ID: 123/9810 Page 10 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division Emission Factors Uncontrolled CAS Pollutant lb/BBL Source loaded 110543 n-Hexane 1.716e-03 AP-42 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) = 50.78 Ib/Ib-mol T (temperature of liquid loaded) = 525 °R Point 005: Emission Emission CAS# Pollutant Weight % Factors Factors Source Uncontrolled Controlled Lb/MMscf Lb/MMscf NOx NA 0.3 NA AP-42 CO NA 0.5 NA Engineering Calculation VOC 35.3 22759.32 1137.9662 VOC Wt. Fraction 71432 Benzene 0.1133 73.0574 3.6529 Engineering Calculation Engineering 108883 Toulene 0.1009 65.0585 3.2529 Calculation 100414 Ethylbenzene 0.0191 12.3063 0.6153 Engineering Calculation 1330207 Xylenes 0.0094 26.2908 1.3145 Engineering Calculation 110543 n-Hexane 0.8286 533.702 26.6851 Engineering Calculation Note: The controlled 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 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%) _ 35.31 100 99.9 80.49 Benzene Content(wt%) 0.11 0.89 1.01 Toulene Content(wt%) 0.10 2.28 0.66 Ethylbenzene Content (wt%) 0.02 0.95 0.08 Xylene Content(wt%) 0.04 2.47 0.19 n-Hexane 0.83 5.24 6.68 AIRS ID: 123/9810 Page 11 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents 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. 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. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this • permit is valid for a term of five years. The five-year term for this APEN expires on April 16,. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 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/fr18ja08.pdf 7) Point 003:This engine is subject to 40 CFR, Part 63, Subpart ZZZZ-National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.qov/ttn/atw/area/arearules.html 8) This facility is classified as follows: Applicable Status Requirement OP Synthetic Minor Source AIRS ID: 123/9810 Page 12 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division NANSR Synthetic Minor Source MACT HH Area Source Requirements: Not Applicable MACT ZZZZ Area Source Requirements 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at , the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK 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 10) 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/oilqaspermittinq.html AIRS ID: 123/9810 Page 13 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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: 123/9810 Page 14 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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 2004 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. 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 AIRS ID: 123/9810 Page 15 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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 naturalgas 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 PM10: 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. 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. AIRS ID: 123/9810 Page 16 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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, § 1.6 (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 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 AIRS ID: 123/9810 Page 17 of 18 Marathon Oil Company Colorado Department of Public Health and Environment Air Pollution Control Division 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: 123/9810 Page 18 of 18 Hello