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Home My WebLink About20120929.tiff STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina, MD,MPH ,of'c04o� Executive Director and Chief Medical Officer /k '; Dedicated to protecting and improving the health and environment of the people of Colorado q, qf. '>4 4300 Cherry Creek Dr.S. Laboratory Services Division 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 March 29, 2012 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 EOG Resources Inc. This public notice will be published in the Greeley Tribune on April 3, 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, CC Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division P1/4:,\j\'c �Zv.'ifLv cL Ptf 14-1.. 2012-0929 -q- 1a 4-3 is NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR OIL AND NATURAL GAS PRODUCTION PLANT BY EOG Resources, Inc. CONTENTS 1 . PUBLIC NOTICE 2. PRELIMINARY ANALYSIS 3. AIR POLLUTANT EMISSION NOTICES • 4. DRAFT PERMIT PREPARED BY: OLUWASEUN OGUNGBENLE COLORADO DEPARTMENT OF PUBLIC HEALTH & ENVIRONMENT 4300 CHERRY CREEK DRIVE SOUTH, APCD-SS-B1 DENVER, CO 80246-1530 STATE OF COLORADO John W. Hickenlooper,Governor Christopher E. Urbina,MD, MPH .oP• COLoi Executive Director and Chief Medical Officer 4v- 4FT � o Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Laboratory Services Division 'rals• 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 Released to: The Greeley Tribune on March 29, 2012; published on April 3, 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: EOG Resources, Inc. proposes to construct and operate an oil and natural gas production facility known as the • Randall Creek 4-32H Oil and Gas Production Facility. This source will be designed to process 255 MSCF per day of natural gas and will be located at Section 32 of Township 12 North, Range 62 West in Weld County. The source would be considered a major source of air pollutants subject to Prevention of Significant Deterioration (PSD) and Maximum Achievable Control Technology (MACT) requirements if the operator did not install emissions controls and accept federally enforceable emissions limits in the proposed permit. Since the operator will accept emissions limits less than 250 tons per year for each criteria pollutant and less than 10 tons per year any single hazardous air pollutant (HAP)and 25 tons per year total combined HAP, this source will be considered a synthetic minor source not subject to PSD or MACT review. The source will have permitted emissions less than 100 tons per year for criteria pollutants and will be considered a synthetic minor source, not subject to Title V Operating Permit requirements. As such, this permit is subject to public comment per Regulation 3, Part B, Section III.C.1.d. Copies of the draft permit and preliminary analyses are available for review in the public comment package. The Division has determined that the proposed source will comply with all applicable regulations and standards of the Colorado Air Quality Control Commission and has made a preliminary determination of approval of the application. 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-B1 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 25-7-1 14.5(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. Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3206 Source Name: Randall Creek 4-32H Source Location: SESE Sec. 32, T12N, R62W Point 001 -One (1)Truck Loadout Operation Point 002 -One (1) Reciprocating Internal Combustion Engine for Electricity Generation Point 003 -One (1)Tornado Flare Equipment Description: Point 004-One(1)400 BBL Emergency Tank used when treater gas needs to be vented to the atmosphere Point 005 -One (1)400 BBL fixed roof Produced Water Storage Tank Point 006 -Six(6)400 BBL fixed roof Crude Oil Storage Tanks Point 007 - Fugitive emissions from valves, flanges, connectors, and other components AIRS ID: 123-9330 Date: 02/28/2012 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? February 14, 2012 Section 4—Source Description AIRS Point Equipment Description 001 One (1) Truck Loadout Operation 002 One (1) Reciprocating Internal Combustion Engine (Waukesha, F1197GU, 329772) for Electricity Generation 003 One (1)Tornado Flare (Tornado,40' Flare Stack, 10856-18) 004 One (1)400 BBL Emergency Tank (Connor, EOG#4495, 30671) used when treater gas needs to be vented to the atmosphere Page 1 005 One 11)400 BBL fixed roof Produced Water Storage Tank • 006 Six(6) 400 BBL fixed roof Crude Oil Storage Tanks _ 007 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 Yes X No pollutant? If"yes", for what pollutant? PM,() 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 PM,o 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 Yes X No Regulation 7, Sections XII and XVII.C may apply) Section 5-Emission Estimate Information AIRS Point Emission Factor Source 001 AP-42, Table 5.2-1, equation 1 Emission Factors for NOx, CO and VOC are from Manufacturer Data. 002 Emission Factors for formaldehyde, acetaldehyde, Acrolein, and Benzene are from AP-42, Table 3.2-3 Emission Factors for NOx, CO, and PM10 are from AP-42, Table 13.5-1 SO2 emissions are based on AP-42, Table 1.4-2, which is based on 2000 grains S/MMscf • and 100% conversion. 003 • Maximum gas vented to atmosphere along with VOC weight fraction to determine a site- specific emission factor. Note: the sampling was completed at the Critter Creek 2-03H site rather than Randall Creek 4-32H. Site specific sampling will be required by the permit to verify the emission factors developed for the permit application. VOC E.F.= 33643 lb/MMscf vented VOC emissions are based on a VOC weight-fraction as for Point 003. 004 VOC E.F.= 33647.5 lb/MMscf vented 005 State default emission factors for produced water tanks in Weld County. Source used E&P Tank model and site specific sampling to develop site-specific emission factors in lb/bbl units. Note: the sampling was completed at the Critter Creek 2-03H site 006 rather than Randall Creek 4-32H. Site specific sampling will be required by the permit to • verify the emission factors developed for the permit application. VOC E.F.= 0.1348 lb/bbl • 007 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 001 182,500 BBUyr crude oil and produced water throughput 002 7.2 MMscf/yr Annual Fuel Consumption 003 93.075 MMscf/yr(0.255 MMscf/d) natural gas venting to flare 004 0.417 MMscf/yr (11,583.3 scf/hr x 3 events x 12 hours/event) natural gas venting 005 73,000 BBUyr produced water throughput 006 131, 400 BBUyr crude oil throughput Page 2 Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory' AIRS Point Process Consumption/Throughput/Production Data Year Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 182,500 BBUyr crude oil and produced water throughput 002 9.5 MMscf/yr Annual Fuel Consumption 003 93.075 MMscf/yr(0.255 MMscf/d) natural gas venting to flare 004 0.417 MMscf/yr(11,583.3 scf/hr x 3 events x 12 hours/event) natural gas venting 005 73,000 BBL/yr produced water throughput 006 109, 500 BBL/yr crude oil throughput _ Equipment Type Gas ' Heavy Oil(or Light Oil(or Water/Oil . Heavy Liquid) Light Liquid) Connectors _ 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended Lines 9 . --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 Does this source use control devices? X Yes No % Reduction AIRS Point Process Control Device Description Granted 76% HAP 93 Non-selective catalytic reduction (NSCR)system and air- 65%°% NOx VOC 002 �� fuel ratio controller. 88% co 003 01 Tornado,40' Flare Stack,SN 10856-18 95%VOC a VOC 005 01 Cimarron Smokeless Combustor(SN 1331292) d and HAP 006 01 Cimarron Smokeless Combustor(vapor combustion unit 95% [VC U1) Section 6—Emission Summary (tons per year) Point NOx VOC CO Single HAP Total HAP 001 ---- 9.5 ---- 0.38 (n-Hexane) 0.95 002 17.7 2.6 22.3 0.12 (Formaldehyde) 0.15 003 4.9 1565.2 26.7 21.4 (n-Hexane) 29.1 PTE: 004 ---- _ 7.0 ---- 0.096 (n-Hexane) 0.13 005 ---- 9.6 ---- 0.8(n-Hexane) 1.06 006 0.03 8.9 0.14 0.32(n-Hexane) 0.37 007 ---- 2.4 ---- 0.13 (n-Hexane) 0.14 Total 22.63 1605.2 49.14 23.1 (n-Hexane} 31.9 0.12(Formaldehyde) Page 3 001 ---- 9.5 ---- 0.38 (n-Hexane) 0.95 002 21.3 3.1 26.8 0.15 (Formaldehyde) 0.2 003 4.9 1565.2 26.7 21.4 (n-Hexane) 29.1 Uncontrolled point 004 --- 7.0 ---- 0.096 (n-Hexane) 0.13 source emission rate: 005 ---- 9.6 ---- 0.8 (n-Hexane) _ 1.06 006 0.03 7.4 0.14 0.32 (n-Hexane) 0.37 007 ---- 2.4 ---- 0.13 (n-Hexane) 0.14 Total 26.18 1604.25 53.6 23.1 (n-Hexane) 31.95 0.15(Formaldehyde) 001 ---- 9.5 0.38 (n-Hexane) 1.02 002 1.6 1.1 3.2 0.04 (Formaldehyde) 0.08 003 4.9 78.3 26.7 1.07 (n-Hexane) 1.45 Controlled point 004 ---- 7.0 ---- 0.096 (n-Hexane) 0.13 source emission rate: 005 ---- 0.48 ---- 0.04 (n-Hexane) 0.05 006 0.03 0.37 0.14 0.016 (n-Hexane) 0.018 007 ---- 2.4 ---- 0.13 (n-Hexane) 0.14 Total 6.53 99.15 29.94 1.7 (n-Hexane) 2.9 Total Permitted 6.53 99.15 29.8 1.7 (n-Hexane) 2.9 emissions(tpy): k Section 7--Non-Criteria/Hazardous Air Pollutants AIRS Uncontrolled Are the emissions Controlled Emission Point Pollutant CAS# BIN Emission Rate reportable Rate(lb/yr) (lb/yr) Benzene - . 71432 A 127 Yes 127 Toluene 108883 C 416 No 416 001 Ethylbenzene 100414 C 31 No 31 Xylenes 1130207 C 553 No 553 ' n-Hexane 110543 C 758 No 758 2,2,4-Trimethylpentane 540841 C 161 No 161 Benzene 71432 A 23 No 6 Toluene 108883 C 8 No 2 Xylenes 1130207 C 3 No 1 002 1,3-Butadiene 106990 A 10 No 2 Formaldehyde 50000 A 302 Yes 72 Acetaldehyde , 75070 A 41 No 10 Acrolein 107028 A 39 No 9 Methanol 67561 C 45 No 11 Benzene 71432 A 6981 Yes 349 Toluene 108883 C 5271 Yes 264 003 Ethylbenzene 100414 C 886 No 44 Xylenes 1130207 C 2190 Yes 109 n-Hexane 110543 C 42799 Yes 2140 2,2,4-Trimethylpentane 540841 C 84 No 4 Benzene 71432 A 31 No 31 Toluene 108883 C 24 No 24 004 Ethylbenzene 100414 C 4 No 4 Xylenes 1130207 C 10 No 10 n-Hexane 110543 C 192 No 192 2,2,4-Trimethylpentane 540841 C 0.4 No 0.4 005 Benzene 71432 A 511 Yes 26 n-Hexane 110543 C 1606 Yes 80 Benzene 71432 A 96 Yes 5 Toluene 108883 C 84 No 4 006 Ethylbenzene 100414 C 2 No 0 Xylenes 1130207 C 32 No 2 n-Hexane 110543 C 638 No 32 2,2,4-Trimethylpentane 540841 C 52 No 3 007 Benzene 71432 A 8 No 8 Page 4 . Toluene 108883 C 12 No 12 Ethylbenzene 100414 C 2 No 2 Xylenes 1130207 C 4 No 4 n-Hexane 110543 C 252 No 252 Note: Regulation 3, Part A, Section 1I.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 002 01 NOx,CO, Regulation No. 3, Part B., Section III.G.3 Stack test 003 01 VOC, State only requirement Site-specific gas HAPS analysis 004 01 VOC, State only requirement Site-specific gas HAPS analysis Site-specific 006 01 VOC CDPHE PS Memo 05-01 sampling 007 01 VOC, State only requirement Hard component HAPS count Section 9—Source Classification Is this a new previously 001 002 003 004 005 006 007 un-permitted source? YES Yes Yes Yes Yes Yes Yes Yes What is this point classification? True Minor X X X X X X Synthetic Minor X Major What is this facility True X Synthetic Minor Major classification? Minor Classification relates to Title X X PSD NANSR X MALT what programs? V Is this a modification to an Yes X No existing permit? If"yes"what kind of Minor Synthetic Minor Major modification? Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No • If"yes",for which pollutants?Why? _ 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)? X 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 Yes X No Air Quality Standards(NAAQS)? i Page 5 If"yes", for which pollutants?Why? AIRS Point Section 12— Regulatory Review Regulation 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, 001-007 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 001-007 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 001-007 each individual emission point in an attainment area with uncontrolled actual emissions of two tons per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is in attainment. (Applicant is required to file an APEN since emissions exceed 2 tons per year VOC) Part B—Construction Permit Exemptions 001-007 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 5.0 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 001-007 non-attainment areas This source is not subject to this requirement because it is located in an ozone attainment area. Regulation 6 - New Source Performance Standards 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. 002 Engine manufacture dateprovided by applicant(February 25, 1979) is prior to the 9 PP threshold date; therefore, this engine is not subject to NSPS JJJJ. NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 004, 005, 006 These tanks are not subject to NSPS Kb because they each have a capacity less than 471 BBL. 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). 007 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. Page 6 Regulation 7—Volatile Organic Compounds This engine is subject to Regulation 7, Section XVII.E because it was relocated into 002 the State of Colorado on 12/18/2010,which is after January 1, 2008. XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is not subject to the emission control requirements for condensate tanks 004, 005, because this facility is located in an attainment area. 006 XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is not currently subject to this section because these are not condensate storage tanks. Section XII.G: If facility is a natural gas processing plant located in non-attainment area,then subject to Section XII.G. 007 This facility is not a natural gas processing plant; therefore, it is not subject to this part. Regulation 8 Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution 001, 004, This source is not subject to MACT EEEE because it is not located at a major source of 005, 006 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 ZZZZ: Engines subject to area source MACT ZZZZ are engines with a commencement of construction date on or after June 12, 2006. • 002 Based on the date of order and date of relocation provided by the operator, this generator engine is considered a new area source under MACT ZZZZ (i.e. the date of commencement of construction is after June 12, 2006). The engine is therefore subject to • NSPS JJJJ requirements; however, this engine has no requirements under NSPS JJJJ. Section 13-Aerometric Information Retrieval System Coding Information Point Process Process Emission Pollutant/ Fugitive Emission Factor Source Control Description Factor CAS# (YIN) (%) 2.47 VOC No AP-42 NA lb/1000 gal 0.0007 Benzene No AP-42 NA lb/BBL Crude Oil and 0.0023 Toluene No AP-42 NA lb/BBL 01 Produced Water 001 Truck Loadout 0.0002 Ethylbenzene No AP-42 NA lb/BBL 0.0030 Xylenes No AP-42 NA lb/BBL 0.0042 n-hexane No AP-42 NA lb/BBL SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Process Emission Pollutant/ Fugitive Emission Factor Control Point Process Description Factor CAS# (Y/N) Source (%) 2.0 g/hp-hr VOC No Manufacturer 65 13.5 g/hp-hr NOx No Manufacturer 93 Reciprocating 17.0 g/hp-hr CO No Manufacturer 88 002 01 Internal 0.0205 Combustion Ib/MMBtu Formaldehyde No AP-42 76 Engine 0.00279 Acetaldehyde No AP-42 76 lb/MMBtu 0.00263 Acrolein No AP-42 76 Ib/MMBtu Page 7 0.00158 Benzene No AP-42 76 lb/MMBtu scC 20200253:4-cycle rich burn Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (YIN) Emission Factor Source (%) 33642.97 VOC No VOC Wt Fraction 95 Ib/MMscf 0.068 NOx No AP-42, NA lb/MMBtu Table 13.5-1 0.37 CO No AP-42, NA lb/MMBtu. Table 13.5-1 75.0282 01 Flare Benzene No Engineering Calculation 95 lb/MMscf 003 56.6516 Toluene No Engineering Calculation 95 lb/MMscf 9.5245 Ethylbenzene No Engineering Calculation 95 lb/MMscf 23.5311 Xylenes No Engineering Calculation 95 lb/MMscf 460.0056 n-hexane No Engineering Calculation 95 lb/MMscf SCC 31000205: Flares (Natural gas production) Point Process Process Emission Pollutant/ Fugitive Emission Factor Source Control Description Factor CAS# (Y/N) ( ) CDPHE PS Memo 05- 33647.5 VOC No 01 NA lb/MMscf (converted to lb/1000 gal) 75.0282 Benzene No Engineering Calculation NA lb/MMscf 01 Natural gas 56.6516 Toluene No Engineering Calculation NA 004 blowdown venting lb/MMscf g g 9.5245 Ethylbenzene No Engineering Calculation NA lb/MMscf 23.5311 Xylenes No Engineering Calculation NA lb/MMscf 460.0056 n-hexane No Engineering Calculation NA lb/MMscf SCC 31000299—Natural Gas Production: Other not classified Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (YIN) Emission Factor Source_____c%) 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 95 005 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# (YIN) Source __ 3.21 VOC No Site-specific 95 lb/1000 gal 0.0209 Benzene No E&P Tanks 95 006 01 E&P Crude oil lb/1000 gal Storage Tanks 0.0186 Toluene No E&P Tanks 95 lb/1000 gal 0.0003 Ethylbenzene No E&P Tanks 95 lb/1000 gal Page 8 0.007 Xylenes No E&P Tanks 95 lb/1000 gal 0.1387 n-Hexane No E&P Tanks 95 lb/1000 gal 0.0113 2,2,4-TMP 4-TMP No E&P Tanks 95 lb/1000 gal SCC 40400312— Fixed Roof Tank, Crude Oil,working+breathing+flashing losses Process Emission Pollutant/ Fugitive Emission Factor Control Point Process Description Factor CAS# (Y/N) Source (%) 01 Fugitive VOC VOC Yes EPA-453/R-95- NA 01 007 Leak Emissions 017, Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14— Miscellaneous Application Notes AIRS Point 001 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 5.18 Psia, M 33.43 lb/lb-mole T 524 deg. R L 2.47 lb/103 gal 0.104 lb/bbl Annual requested Throughput 7665000 gal/yr Annual requested VOC emissions 18937 lb/yr 9.5 tpy AIRS Point 002 Stationary RICE This is a permitted source since uncontrolled NOx and CO emissions are each greater than 10 TPY. Engine is not subject to federal requirements, and since it was relocated into Colorado on 12/18/10, it is subject to Regulation 7 requirements. The engine is controlled by an NSCR and AFRO. Page 9 AIRS Point 003 Tornado Flare The tornado flare is used to control gas production since there is no pipeline available in the area at this time. EOG will continue to flare gas until a pipeline is available. Emissions were calculated using VOC wt fraction. (scf/hr) * (Ib/Ib-mol) *(% fraction from sales gas analysis)/(379.4 scf/lb-mol) = lb/hr* (hr/yr) /2000 lb/T) = TPY VOC = (1565.7 TPY*2000 lb/T)/ (93.1 mmscf/yr) = 33642.971b/MMscf NOx and CO (from AP-42, Chapter 13, Table 13.5-1 (NOx = 0.068 lb/MMbtu; CO = 0.37 lb/MMbtu) SO2 emissions are based on AP-42 Table 1.4-2 (SO2 = 0.00037 lb/MMBtu) PKo and PMz_5 are based on AP-42 Table 13.5-2 (PM10 and PM2.5=40 ug/l) Benzene = (6981.4 Ib/yr)/ 93.1 mmscf/yr= 75.0282 lb/mmscf Toluene = (5271.5 lb/yr)/93.1 mmscf/yr= 56.6516 lb/mmscf Ethylbenzene = (886.3 Ib/yr)/93.1 mmscf/yr= 9.5245 lb/mmscf Xylenes= (2189.6 lb/yr)/93.1 mmscf/yr= 23.5311 lb/mmscf n-Hexane = (42798.8 Ib/yr) /93.1 mmscf/yr=460.0056 lb/mmscf AIRS Point 004 Emergency Storage Tank Emissions were calculated using VOC wt fraction using a sales gas analysis from the facility dated August 9, 2010. (scf/hr) *(Ib/Ib-mol) *(% fraction from sales gas analysis) / (379.4 scf/lb-mol) = lb/hr* 12 hrs/event * 3 events/yr/2000 lb/T) =TPY VOC = (7.0 TPY *2000 lb/T) /(0.417 mmscf/yr) = 33647.5 lb/mmscf Benzene = (31.3 lb/yr)/(0.417 mmscf/yr) = 75.0282 lb/mmscf Toluene = (23.6 lb/yr)/(0.417 mmscf/yr) = 56.6516 lb/mmscf Ethylbenzene = (4.0 Ib/yr)/(0.417 mmscf/yr) = 9.5245 lb/mmscf Xylenes = (9.8 lb/yr)/(0.417 mmscf/yr) = 23.5311 lb/mmscf n-Hexane = (191.6 Ib/yr) /(0.417 mmscf/yr) = 460.0056 lb/mmscf AIRS Point 005 Produced Water Storage Tanks EOG used the state default emission factors to calculate emissions from this produced water storage tank battery. 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. There is a categorical exemption for such source (Regulation 3, Part B, Section II.D.1.m). However, EOG will not take advantage of this categorical exemption in order to avoid being considered a major source of VOC for Operating Permit applicability. Without controls the overall permitted VOC emissions would be greater than 100 TPY. The operator has requested synthetic minor status and accepts Federally enforceable controls, and therefore, this source needs to be included in the overall facility for synthetic minor eligibility. Page 10 AIRS Point 006 Crude Oil Storage Tanks Site-specific emission factor using E&P Tanks: VOC = (7.4 TPY*2000)/ 109500 bbl/yr= 0.1348 lb/bbl *1000/42 = 3.21 lb/1000 gal Benzene = (0.048 TPY * 2000)/ 109500 bbl/yr= 0.00088 lb/bbl * 1000/42 = 0.0209 lb/1000 gal Toluene= (0.042 TPY*2000)/ 109500 bbl/yr= 0.00078 lb/bbl *0.0183 lb/1000 gal Ethylbenzene = (0.001 TPY * 2000)/ 109500 bbl/yr= 0.000018 lb/bbl * 1000/42 = 0.0004 lb/1000 gal Xylenes = (0.016 TPY *2000)/ 109500 bbl/yr= 0.00029 lb/bbl * 1000/42 = 0.007 lb/1000 gal n-Hexane = (0.319 TPY*2000)/ 109500 bbl/yr= 0.0058 lb/bbl * 1000/42 = 0.1387 lb/1000 gal 2,2,4-TMP = (0.026 TPY * 2000)/ 109500 bbl/yr= 0.000475 lb/bbl * 1000/42 = 0.0113 lb/1000 gal AIRS Point 006 Fugitive VOC Leak Emissions A permit exempt will be issued because the facility-wide uncontrolled V0C emissions are greater than 5 TPY (permit threshold). When reviewing calculations for a similar facility in a non-attainment area, Stephanie Chaousy noticed that the fugitive emissions were wrongly calculated. These errors caused fugitive emissions to be estimated at 1.5 TPY instead of 2.4 TP. E0G submitted revised APENS for the fugitive emissions on 2/14/12. Facility All Facility wide review wide points A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and facility is synthetic minor source with respect to VOC, PSD, n-Hexane, and total HAPS. • This source is not located in the 8-hour ozone non-attainment area (This portion of Weld county is in attainment). Page 11 N 0 0 .. _ _ > > O O _ q O o o O_ O • F O G H a X A A 3 4 .n o ti t LCD 2. O. O _ rn re, en ne = N A >' 0 `c '0 n n a Cl m N N N _ 0 O 0 O O O co O ` p. ,. 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"1- p i E o1..•• o T v 0 i# O c m o U F H a > in a Q . o Z > ai o x x o m .ro u 011 sn • 0Cr Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY Current Status(Check all that apply) - tt --y Reason for APEN Submittal(Check all that apply) AIRS ID#': (b3 9339 Bob `,,_-�jy- ❑ APEN update only° ® New or previously unreported battery`•'o% 2J'-. ❑ Modification to existing source' ❑ Previously grandfathered battery- 'i "-"'t ❑ Registration for coverage under general permit no.GPOI ElSynthetic minor facility S[c. -C '? / &cancellation request for individual permit': ❑ Located in the 8-hr Ozone ControlAteak]t-,, ® -Application for or Modification of an individual permit ❑ Registered under general permit noll•GPOk.,=� I] Administrative permit amendment' El Permitted under individual permit: •-.. I(4e32m6 ❑ 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 Name': EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 17"1 Street,Suite 1000N david_long@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long Phone: 303-262-9448 Fax: 303-262-9449 Tank Battery Nameu: Randall Creek 4-32H Number of tanks: 6 Location"-(QQ Sec.Twp.Range.): SESE Sec 32,T12N,R62 W County: Weld Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies'3: 2011 Year(s)tank(s)were placed in service'4: 2011 Control Description's: Cimarron Smokeless Combustor(vapor combustion unit[VCU]) Control Efficiency 6: 95% Condensate Throughput17[bbl/year] Requested's: 109,500 Maximum for PTE calculation'": 131,400 Actual'-°: 109,500 While Controls Operational' 109,500 Other equipment at facility": VCU.flare,heater treater,generator engine,line heater,produced H2O tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPOI coverage. Therefore,an individual permit is being requested. 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 emissions-s. Emission Factor Battery Requested Emissions's Actual Emissions'° • Pollutant'° [lb/bbl] PTE25 Uncontrolled'6 Controlled" Uncontrolled'° Controlled"VOC[tons/year] 0.1348 8.9 N/A N/A 7.4 , 0.37 NOx[tons/year] N/A 0.03 0.03 0.03 CO[tons/year] N/A 0.14 0.14 0.14 • Benzene[lbs/year] 0•6)5Dgi 7C1 )I5- 96.0 4.8 n-Hexane[lbs/year] Q -ao5g '7 6-5-g 638.0 31.9 Wells serviced by this tank or tank batteryra API#: 05-123-31233-00 Name: Randall Creek 4-32FI ®Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well t—' API#: Name ❑Newly Reported Well rV • W API#: Name: ❑Newly Reported Well ," in co API#: Name: ❑Newly Reported Well __ W CD u.^t i The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the besfl!of CD my knowledge and belief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated CD m in full corn lance with eadm 0 nditi•...air en- . permit GPO I. �.�.c. I'' / (—//;-// tri- ZSignature /•'%� _ '-rson n• . vendor or consultant) Date r' N David on Division Environmental Manager mA � Type or Print Name of Person Signing Above Official Title o Submit this form,along with$152.90 for each Colorado Department of Public Health and Enviro ent-,mri _For information call: °' filing of up to 5 tank battery APENS. 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O F C U W a' 0 Y '.? T cn V] ❑ Y Cl o a Y q O c w y vi m a. '° o y E 8 Y w y a' w ° e E o L4 4 . •.6 v" a e N E. o a ° (..'J d w N q '. C Y O > o y ° L 44414 Z R E a R ❑ h C a._ ❑ EL. ° G Y d v, C o Y m > E nbi a 0. a E q =' Gy m �3 oe rn h n o-. o I� w .+ To e w i0 c 2 o Ya h a a C p N' ° G ° . U . C G o t° 3 Err O °a a° � °° w y „ - '1-'5 N _ W M v a a - Z m I u a C m 9 m _ a m C Y v a, Yo o T o O Co N W o d ° C Y o E U Y y C E R C E y C or V D 'Es d v v u'1 a y C° W 2 U G C r °a o o .o a>'. o- 'U Q' o A a m 7; > fb F X U '. c D11.A.FT STATE OF COLORADO 0v.coto COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT $ AIR POLLUTION CONTROL DIVISION * 4 * iw TELEPHONE: (303) 692-3150 .1876* CONSTRUCTION PERMIT PERMIT NO: 11WE3206 WE3206 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and Natural gas exploration and production facility, known as the Randall Creek 4-32H, located in SESE Section 32, Township 12N, Range 62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point Truck 001 Truck loadout of crude oil and produced water. Loadout One (1) Waukesha, Model F1197GU, Serial Number 329772, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 136 Generator 002 horsepower at 1800 RPM. This engine shall be equipped RICE Engine with a non-selective catalytic reduction (NSCR) system and air-fuel ratio controller. This emission unit is used to power a generator for the site pending the running of electricity. One (1) Tornado flare (Manufacturer: Tornado, Model No: Flare 003 40' Flare Stack, Serial No: 10856-18) used to combust produced gas vented from a three-phase separator. One (1) 400 BBL Emergency Tank (Connor, EOG #4495, ET#4488 004 30671) used for storage of gas to be vented to the atmosphere in the event it cannot be routed to the flare. Emissions from this point are not controlled. One (1) 400 bbl fixed roof atmospheric produced water PW Tank 005 storage tank. Emissions from this tank are controlled by a smokeless combustor (VCU) with a minimum destruction efficiency of 95%. AIRS ID: 123/9330/001-007 Page 1 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 Air Pollution Control Division Issuance 1 Facility AIRS Description Equipment ID Point Crude Oil Six (6) 400 bbl fixed roof atmospheric crude oil storage Storage 006 tanks. Emissions from these tanks are controlled by a Tanks Cimarron smokeless combustor VCU unit with 95% control efficiency. Fugitive 007 Fugitive emissions from valves, flanges, connectors, and other components. The engine at point 002 may be replaced with another engine in accordance with the temporary engine replacement provision or with another Waukesha F1197GU 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: 123/9330/001-007 Page 2 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 Air Pollution Control Division Issuance 1 EMISSION LIMITATIONS AND RECORDS 6. The applicant shall track emissions from all insignificant activities at the facility on a yearly basis to demonstrate compliance with either the insignificant activities emission limitations or the facility emission limitations as seen below. This information shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Emissions from all insignificant activities from the facility shall be less than: • 3.2 tons per year of volatile organic compounds (VOC), -OR- Total emissions from the facility, including permitted emissions and insignificant activities, shall be less than: • 100 tons per year of volatile organic compounds (VOC), 7. 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 Truck Loadout 001 --- 9.5 --- Point Generator 002 1.6 1.1 3.2 Point RICE Engine Flare 003 4.9 78.3 26.7 Point ET#4488 004 --- 7.0 --- Point PW Tank 005 --- 0.5 --- Point Crude Oil 006 0.4 Point Storage Tanks Fugitive 007 --- 2.4 --- 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. AIRS ID: 123/9330/001-007 Page 3 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11 WE3206 Air Pollution Control Division Issuance 1 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. 8. Point 002: 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 7, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 9. Point 003: The flare shall reduce emissions of VOC to the emission levels listed in condition 7, 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. Point 005: This emissions point shall be configured such that vapors are routed to a combustor (VCU). The VCU shall reduce uncontrolled emissions of VOC to the emission levels listed in condition 7, above. Operating parameters of the control equipment are identified in the Operating and Maintenance Requirement section of this permit. (Reference: Regulation No.3, Part B, Section III.E.) 11. Point 006: This emissions point shall be configured with a combustor unit. The combustor shall reduce the uncontrolled emissions of VOC to the emission levels listed in condition 7, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 12. Point 007: 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 13. 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 Truck Loadout 001 Crude oil and produced water loading 182,500 BBUyr AIRS ID: 123/9330/001-007 Page 4 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 Air Pollution Control Division Issuance 1 Generator 002 Consumption of natural gas as a fuel 9.5 MMSCF/yr RICE Engine Flare 003 Natural gas flaring 93.1 MMSCF/yr ET#4488 004 Natural gas venting to atmosphere 417,000 SCF/yr PW Tank 005 Produced water throughput 73,000 BBL/yr • Crude Oil 006 Crude oil throughput 109,500 BBL/yr Storage Tanks 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 consumption of natural gas and keep a compliance record on site or at a local field office with site responsibility, for Division review. 14. Point 005: Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained • for a consecutive period of three years. STATE AND FEDERAL REGULATORY REQUIREMENTS 15. 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). 16. 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.) 17. 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 II.A.5.). 18. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 19. Point 002: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion 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: AIRS ID: 123/9330/001-007 Page 5 of 22 EOG Resources Inc. Col do p e o Public Health and Environment • Permit No. 11WE3206 Air Pollution Control Division Issuance 1 Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC z100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 20. Point 001: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 21. Points 002, 003, 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.) 22. Point 005: a. VCUs 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 VCU, or by other convenient means approved by the Division, determine whether the VCU is operating properly. b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a VCU include, but are not AIRS ID: 123/9330/001-007 Page 6 of 22 EOG Resources Inc. Co do p e o Public Health and Environment Permit No. 11 WE3206 Air Pollution Control Division Issuance 1 limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its resolution;the date range the control was inoperable, and the produced water production through the battery during the downtime. During control device downtime, emissions shall be considered to be uncontrolled. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 23. Point 002: A source initial compliance test shall be conducted on emissions point 002 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emissions limits contained in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen Carbon Monoxide Volatile Organic Compounds Formaldehyde 24. Point 003: The owner or operator shall demonstrate compliance with Condition 17 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.5). 25. Points 003 and 004: The operator shall complete an initial site specific sample analysis of the natural gas produced at this site that is either routed to the open flame flare or vented through the emergency blowdown tank in order to verify the VOC, Benzene, Toluene, Ethylbenzene, Xylenes, n-Hexane, and 2,2,4-Trimethylpentane content (weight fraction) of this emissions stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division-approved methods Results of this compositional 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. For example, the benzene emission factor shall be calculated according to the following equation using the benzene weight fraction and the natural gas's average molecular weight determined in the site-specific gas analysis: lb benzene lb moi, lb 1 166 rcf x = benzene wt.frac.* * Wan, �. MMscf 379.3 so [lb mod 1MMscf. AIRS ID: 123/9330/001-007 Page 7 of 22 EOG Resources Inc. Col do p e o Public Health and Environment • Permit No. 11WE3206 Air Pollution Control Division Issuance 1 26. Point 006: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized crude oil 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. 27. Point 007: Within one hundred and eighty days (180) after issuance of permit, the permittee shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (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. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 28. Point 007: Within one hundred and eighty days (180) after issuance of permit, 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 29. Point 002: 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. ADDITIONAL REQUIREMENTS 30. 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 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. AIRS ID: 123/9330/001-007 Page 8 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 Air Pollution Control Division Issuance 1 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. f. Point 002: 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. 31. Operating Permit (OP) requirements shall apply to this source at any such time that the facility wide potential to emit equals or exceeds the major source level. Once the facility wide potential to emit equals or exceeds the major source level a Title V operating permit application shall be submitted in accordance with the requirements in Regulation No. 3, Part C. 32. Prevention of Significant Deterioration (PSD) requirements 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 PSD threshold will require a full PSD review of the source as though construction had not yet commenced on the source. The source shall not exceed the PSD threshold until a PSD permit is granted. (Regulation No. 3 Part D, VI.B.4) GENERAL TERMS AND CONDITIONS: 33. 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. 34. 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. 35. 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: 123/9330/001-007 Page 9 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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. 36. 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. 37. 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. 38. 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. 39. 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 for a new synthetic minor E&P facility. AIRS ID: 123/9330/001-007 Page 10 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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 Part II.E.1. of the Common Provisions Regulation. See: http://www.cdphe.state.co.us/regulations/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 (Ib/yr) reportable? Rate(lb/yr) Benzene 71432 A 127 Yes 127 Toluene 108883 C 416 No 416 001 Ethylbenzene 100414 C 31 No 31 . Xylenes 1130207 C 553 No 553 n-Hexane 110543 C 758 No 758 Formaldehyde 5000 A 302 Yes 72 Methanol 67561 C 45 No 11 Acetaldehyde 75070 A 41 No 10 1,3-Butadiene 106990 A 10 No 2 002 Acrolein 107028 A 39 No 9 Toluene 108883 C 8 No 2 Benzene 71432 A 23 No 6 Xylenes 1130207 C 3 No 1 Benzene 71432 A 6981 Yes 349 Toluene 108883 C 5271 Yes 264 Ethylbenzene 100414 C 886 No 44 003 Xylenes 1130207 C 2190 Yes 109 n-Hexane 110543 C 42799 Yes 2140 2,2,4- 540841 C 84 No 4 Trimethylpentane AIRS ID: 123/9330/001-007 Page 11 of 22 EOG Resources Inc. Col do p e o Public Health and Environment • Permit No. 11WE3206 Air Pollution Control Division Issuance 1 Benzene 71432 A 31 No 31 Toluene 108883 C 24 No 24 Ethylbenzene 100414 C 4 No 4 004 Xylenes 1130207 C 10 No 10 n-Hexane 110543 C 192 No 192 2,2,4- 540841 C 0.4 No 0.4 Trimethylpentane Benzene 71432 A 511 Yes 26 005 n-Hexane 110543 C 1606 Yes 80 Benzene 71432 A 96 Yes 5 Toluene 108883 C 84 No 4 Ethylbenzene 100414 C 2 No 0 006 Xylenes 1130207 C 32 No 2 n-Hexane 110543 C 638 No 32 2,2,4- 540841 C 52 No 3 Trimethylpentane • Benzene 71432 A 8 No 8 Toluene 108883 C 12 No 12 007 Ethylbenzene 100414 C 2 No 2 Xylenes 1130207 C 4 No 4 n-Hexane 110543 C 252 No 252 4) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors -Uncontrolled CAS Pollutant Ib/BBL Source loaded VOC 0.104 AP-42 71432 Benzene 0.0007 AP-42 108883 Toluene 0.0023 AP-42 100414 Ethylbenzene 0.0002 AP-42 1130207 Xylenes 0.0030 AP-42 110543 n-Hexane 0.0042 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) = 5.18 psia AIRS ID: 123/9330/001-007 Page 12 of 22 LOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11 WE3206 Air Pollution Control Division Issuance 1 M (vapor molecular weight) = 33.43 Ib/Ib-mol T (temperature of liquid loaded) = 524 °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. Point 002: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.1662 13.5000 0.2345 1.0000 CO 3.9871 17.0000 0.4691 2.0000 VOC 0.4691 2.0000 0.1642 0.7000 5000 Formaldehyde 0.0205 0.0874 0.0049 0.0209 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 9400 Btu/hp-hr, a site-rated horsepower value of 136, and a fuel heat value of 1413 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 AP42, Tab. 3.2-3 AP42, Tab. 3.2-3 75070 Acetaldeh de AP-42; Table 3.2-3 (7/2000); AP42, Tab. 3.2-3 y 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 003: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled NOx --- 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42 CO --- 0.37 Ib/MMBtu 0.37 lb/MMBtu AP-42 VOC 46.18 33642.97 1682.15 Engineering Ib/MMscf lb/mmscf Calculation PM%) --- 40 ug/l 40 ug/l AP-42, Table 13.5-1 AIRS ID: 123/9330/001-007 Page 13 of 22 EOG Resources Inc. Col do p e o Public Health and Environment . Permit No. 11WE3206 Air Pollution Control Division Issuance 1 Weight Emission Emission CAS # Pollutant Fraction of Factors Factors Gas (%) Uncontrolled Controlled Source SOx __ 0.00037 0.00037 0.002 gr/scf lb/MMBtu Ib/MMBtu 71432 Benzene 0.10 75.0282 3.7514 Engineering lb/MMscf lb/mmscf Calculation 108883 Toluene 0.08 56.6516 2.8326 Engineering lb/MMscf lb/mmscf Calculation 100414 Ethylbenzene 0.01 9.5245 lb/MMscf 0.4762 Engineering lb/mmscf Calculation 1330207 Xylenes 0.03 23.5311 1.1766 Engineering lb/MMscf lb/mmscf Calculation 110543 n-Hexane 0.63 460.0056 23.000 Engineering lb/MMscf lb/mmscf Calculation 540841 2,2,4-IMP 0.0012 0.9042 lb/MMscf 0.0452 Engineering lb/mmscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 9, 2010 analysis of a gas sample collected from the Critter Creek 2-03H well. The controlled VOC and HAP emissions factors for point 003 are based on the flare control efficiency of 95%. • Point 004: Emission Factors Weight Fraction of Source CAS# Pollutant Uncontrolled Gas (%) Lb/MMscf VOC 33647.5 lb/MMscf 46.18 Engineering Calculation 71432 Benzene 0.10 Engineering 75.0282 lb/MMscf Calculation 108883 Toluene 0.08 Engineering 56.6516 lb/MMscf Calculation 100414 Ethylbenzene 0.01 Engineering 9.5245 Ib/MMscf Calculation 1330207 Xylenes 0.03 Engineering 23.5311 lb/MMscf Calculation 110543 n-Hexane 0.63 Engineering 460.0056 Ib/MMscf Calculation 540841 2,2,4-TMP 0.0012 Engineering 0.9042 Ib/MMscf Calculation The emission levels in this permit for this point are based on the use of this tank to blowdown produced natural gas when the flare used to combust the natural gas is down at three (3) events per year and twelve (12) hours of venting through this tank per event at a maximum gas flow rate of 11,583.3 scf/hr. The VOC content of the produced gas used in the application was based on a gas sample from the Critter Creek 2-03H well (weight percents for VOC and HAP components from this analysis are listed in the table above). AIRS ID: 123/9330/001-007 Page 14 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 Air Pollution Control Division Issuance 1 Point 005: 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 005 are based on a combustor control efficiency of 95%. Points 006: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42, Table 13.5-1 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42, Table 13.5-1 VOC 0.1348 lb/bbl 0.00674 lb/bbl E&P Tanks 71432 Benzene 8.77E-04 lb/bbl 4.38E-05 lb/bbl E&P Tanks 108883 Toluene 7.67E-04 lb/bbl 3.84E-05 lb/bbl E&P Tanks 100414 Ethylbenzene 1.83E-05 lb/bbl 9.13E-07 lb/bbl E&P Tanks . 1330207 Xylenes 2.92E-04 lb/bbl 1.46E-05 lb/bbl E&P Tanks 11Q543 n-Hexane 5.83E-03 lb/bbl 2.91 E-04 lb/bbl E&P Tanks 540841 2,2,4-TMP 4.75E-04 lb/bbl 2.37E-05 lb/bbl E&P Tanks Note: The controlled emissions factors for point 006 are based on a combustor control efficiency of 95%. These emission factors were developed using a pressurized liquids analysis from the Critter Creek 2-03H well. Point 007: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open-Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 • VOC Content(wt%) 3.5% --- 29.2% 100% Benzene Content(wt%) 0.023% --- 0.027% a 12 Toluene Content(wt%) 0.039% --- 0.075% 0.032 Ethylbenzene (wt%) 0.002% --- 0.017% 0.001 Xylenes Content(wt%) 0.01% --- 0.036% 0.004 n-hexane Content(wt%) 0.338% --- 2.43% --- *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): AIRS ID: 123/9330/001-007 Page 15 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No, 11 WE3206 Air Pollution Control Division Issuance 1 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, the Air Pollutant Emission Notices (APENs) associated with this permit are valid for a term of five years. The five-year terms for these APENs expire as listed below. A revised APEN shall be submitted no later than 30 days before the five-year term expires. AIRS Points APEN Expiration 001-006 August 22, 2016 007 February 13, 2017 6) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source VOC, n-Hexane, Total HAPs PSD Synthetic Minor Source VOC, n-Hexane, Total HAPs MACT ZZZZ Major Source Requirements: Not Applicable Area Source Requirements: New Area Source 7) 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 AIRS ID: 123/9330/001-007 Page 16 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 Air Pollution Control Division Issuance 1 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 7777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 8) An OH 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.cdohe.state.co.us/ap/oilqaspermittinghtml • AIRS ID: 123/9330/001-007 Page 17 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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: 123/9330/001-007 Page 18 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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 grandfathere.d 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: 123/9330/001-007 Page 19 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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 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. AIRS ID: 123/9330/001-007 Page 20 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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 8, § 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: 123/9330/001-007 Page 21 of 22 EOG Resources Inc. Col do p e o Public Health and Environment Permit No. 11WE3206 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 777Z. 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: 123/9330/001-007 Page 22 of 22 Hello