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Home My WebLink About20120908.tiff STATE OF COLORADO John W.Hickenlooper,Governor Christopher E. Urbina,MD,MPH .0? co.%R Executive Director and Chief Medical Officer N`` Dedicated to protecting and improving the health and environment of the people of Colorado * ,� 4300 Cherry Creek Dr.S.Laboratory Services Division,187s 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 28, 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 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, Ellen Evans Public Notice Coordinator Stationary Sources Program Air Pollution Control Division SJ%?- ocin� LA - zi-1 �- NOTICE OF REQUEST FOR SYNTHETIC MINOR PERMIT FOR CRUDE OIL AND NATURAL GAS PRODUCTION FACILITY BY EOG Resources, Inc CONTENTS 1 . PUBLIC NOTICE 2. PRELIMINARY ANALYSIS 3. AIR POLLUTANT EMISSION NOTICES 4. DRAFT PERMIT PREPARED BY: JOSHUA JONES 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 ;oF.co.coR Executive Director and Chief Medical Officer x „t Dedicated to protecting and improving the health and environment of the people of Colorado *1 * 4300 Cherry Creek Dr. S. Laboratory Services Division •" Denver,Colorado 80246-1530 8100 Lowry Blvd. tees 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 28, 2012; published on April 4, 2012 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT The Colorado Air Pollution Control Division declares the following proposed construction activity warrants public comment. Therefore, the Air Pollution Control Division of the Colorado Department of Public Health and Environment hereby gives NOTICE, pursuant to Section 25-7-114.5(5), C.R.S. of the Colorado Air Quality Control Act that the Division received an application for an air pollution emission permit on the following proposed project and activity: EOG Resources, Inc. proposes to construct and operate an oil and natural gas production facility known as the Lion Creek 7-24H site. This source is located approximately 14 miles west of Grover in SWSE Section 24 of Township 11 North, Range 64 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 for any single hazardous air pollutant(HAP) and 25 tons per year for total combined HAPs, 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 related to Title V Operating Permit requirements. As such, this permit is subject to public comment per Regulation 3, Part B, Section III.C.I.d. Copies of the draft permit and preliminary analysis 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: Joshua Jones 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 25-7-114.5(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. Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: EOG Resources Permit Number: 11 WE3110 Source Name: Lion Creek 7-24H Source Location: SWSE Sec 24,T11N, R64W Point 001 —Six (6)400 BBL Crude Oil Storage Tanks Point 002—One (1)400 BBL Produced Water Storage Tank Point 003—One (1) 400 BBL Emergency Tank for storage of vented gas Equipment Description: Point 004—One (1) Tornado Flare Point 005—Crude Oil Tank Truck Loadout Point 006—4SRB Internal Combustion Engine Point 007—Fugitive Emissions AIRS ID: 123-9314 Date: March 28, 2012 Review Engineer: Joshua Jones Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 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? 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 Six(6) above ground 400 bbl atmospheric crude oil storage tanks controlled by a vapor combustion unit 002 One (1) above ground 400 bbl atmospheric produced water storage tank controlled by a vapor combustion unit 003 One (1) emergency tank for storage of gas to be vented to atmosphere 004 One (1) Tornado Flare for flaring of all gas produced at plant controlled by a 40ft non-enclosed flare stack Page 1 005 Crude oil tank truck loadout One(1) International 4 stroke rich burn natural gas fired internal combustion engine 006 (model NG466TA, serial#674774-65)equipped with a non-selective catalytic reduction system ( NSCR) and an air/fuel ratio controller. 007 Equipment leaks (fugitive VOCs) Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? Is this location in an attainment maintenance area for Yes X No any criteria pollutant? 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 Site specific emissions factors developed using E&P Tanks and natural gas liquids 001 analysis from similar facility (Critter Creek 2-03H, dated Aug 09, 2010). EFs (lb/bbl): VOC = 0.1341, Benz = 0.00086, n-Hex= 0.0059 002 CDPHE Produced Water Storage Tank Emission Factors for Weld county; CDPHE Memo 09-02 Site specific emissions factors using weight fraction from sales gas analysis (from Critter 003 Creek 2-03H facility, dated Aug 09, 2010) and predetermined upset events (details in section 14) VOC EF = 33588.77 lb/mmscf vented Site specific emissions factors using weight fraction from sales gas analysis (from Critter 004 Creek 2-03H facility, dated Aug 09, 2010, calculation details in section 14) VOC EF = 33588.77 lb/mmscf vented AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T 005 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] 006 AP-42 Table 3.2-3: 4SRB 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 001 131,400 BBL per year(109,500 x 1.2) 002 87,600 BBL per year(73,000 x 1.2)wastewater 003 382,500 scf/yr(10,625 scf/hr*12hr/event*3 events/yr) vented 004 255,000 scf/day (93.075 MMscf/yr) vented 005 182,500 BBL/yr condensate loaded 006 7.8 MMscf/yr Page 2 Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 Flanges 8 --- 24 4 007 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 001 109,500 BBL per year 2011 002 73,000 BBL per year wastewater 003 382,500 scf/yr(10,625 scf/hr*12hr/event3 events/yr) 004 255,000 scf/day (93.075 MMscf/yr)vented 005 182,500 BBL/yr condensate loaded 006 7.8 MMscf/yr Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 576 --- 520 51 007 Flanges 8 --- 24 4 Open-Ended 9 ___ 7 5 Lines Pump Seals --- --- 2 -- Valves 56 --- 72 24 Other 35 --- 15 6 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 109,500 BBL per year 002 73,000 BBL per year wastewater 003 382,500 scf/yr(10,625 scf/hr*12hr/event*3 events/yr) 004 255,000 scf/day (93.075 MMscf/yr)vented 005 182,500 BBL/yr condensate loaded 006 7.8 MMscf/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 576 --- 520 51 Flanges 8 -- 24 4 007 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 001 01 Cimarron smokeless combustor(VCU), SN 1331238 95 002 01 Cimarron smokeless combustor(VCU), SN 1331238 95 Page 3 004 01 Tornado 40ft Flare Stack, SN 10670-5 95 NOx 89%; CO 006 01 3-way non-selective catalytic reduction (NSCR)system and 87%;VOC air/fuel ratio controller 57%; other HAPs 50% Section 6— Emission Summa (tons per year) Point NO„ VOC CO Single HAP Total HAP 001 8.8 0.39 (n-Hexane) 0.46 002 11.5 0.96 (n-Hexane) 1.27 003 6.43 0.09 (n-Hexane) 0.12 PTE: 004 1565.2 21.4 (n-Hexane) 29.1 005 9.47 0.38 (n-Hexane) 1.02 006 12.2 2.13 20.54 0.12 0.20 (formaldehyde) 007 2.4 0.13 (n-Hexane) 0.14 001 7.3 0.32 (n-Hexane) 0.37 002 9.6 0.80 (n-Hexane) 1.06 003 6.43 0.09 (n-Hexane) 0.12 Uncontrolled point 004 1565.2 21.4 (n-Hexane) 29.1 source emission rate: 005 9.47 0.38 (n-Hexane) 1.02 006 12.2 2.13 20.54 0.12 0.20 (formaldehyde) 007 2.4 0.13 (n-Hexane) 0.14 Total Uncontrolled 12.2 1602.5 20.54 32.01 001 0.03 0.37 0.14 0.02 (n-Hexane) 0.02 002 0.48 0.04 (n-Hexane) 0.05 003 6.43 0.09 (n-Hexane) 0.12 Controlled point 004 4.90 78.26 26.7 1.07 (n-Hexane) 1.46 source emission rate: 005 9.47 0.38 (n-Hexane) 1.02 0.06 006 1.29 0.91 2.59 0.10 (formaldehyde) 007 2.4 0.13 (n-Hexane) 0.14 Total APEN Reported 6.2 98.3 29.3 2.91 emissions: Insignificants: .31 0.01 .38 0.01 Total all sources: 6.53 98.3 29.81 2.92 Section 7—Non-Criteria/ Hazardous Air Pollutants AIRS Uncontrolled Are the Controlled Point Pollutant CAS # BIN Emission Rate emissions Emission Rate iib/yr) reportable? (Ib/yr) Benzene 71432 A 94 Yes 4.7 001 Toluene 108883 C 84 No 4.2 Ethylbenzene 100414 C 2 No .1 Page 4 Xylenes 1130207 C 32 No 1.6 n-Hexane 110543 C 636 No 31.8 2,2,4- 540841 C 52 No 2.6 Trimethylpentane Benzene 71432 A 511 Yes 25.55 002 n-Hexane 110543 C 1606 Yes 80.3 Benzene 71432 A 28.7 No NA Toluene 108883 C 21.6 No NA Ethylbenzene 100414 C 3.6 No NA 003 Xylenes 1130207 C 9.0 No NA n-Hexane 110543 C 175.8 No NA 2,2,4- 540841 C 0.3 No NA Trimethylpentane Benzene 71432 A 6981.4 Yes 349.1 Toluene 108883 C 5271.5 Yes 263.6 Ethylbenzene 100414 C 886.3 No 44.3 004 Xylenes 1130207 C 2189.6 Yes 109.5 n-Hexane 110543 C 42798.8 Yes 2139.9 2,2,4- 540841 C 84.1 No 4.2 Trimethylpentane Benzene 71432 A 127 Yes NA Toluene 108883 C 416 No NA Ethylbenzene 100414 C 31 No NA 005 Xylenes 1130207 C 553 No NA n-Hexane 110543 C 758 No NA 2,2,4- 540841 C 161 No NA Trimethylpentane Formaldehyde 50000 A 248 Yes 124 Acetaldehyde 75070 A 34 No 17 006 Acrolein 107028 A 32 No 16 Benzene 71432 A 19 No 9.6 Benzene 71432 • A 7.5 No NA Toluene 108883 C 12.2 No NA 007 Ethylbenzene 100414 C 1.7 No NA Xylenes 1330207 C 4.5 No NA n-Hexane 110543 C 252.0 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? Page 5 If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method VOC, Site-specific Liquids 001 01 HAPS PS Memo 05-01 Analyses according to PS Memo 05-01 003 01 VOC, State Only Requirement Site-specific gas HAPS analysis 004 01 VOC, State Only Requirement Site-specific gas HAPS analysis 006 01 NOx CO Regulation No. 3, Part B., Section III.G.3 Stack Test VOC, Regulation No. 3, Part B., Section III.G.3 Site-specific gas HAPs and liquids analysis 007 01 VOC, Component hard HAPs Regulation No. 3, Part B., Section III.G.3 count for equipment leaks Section 9—Source Classification Is this a new previously un-permitted 001 002 003 004 005 006 007 source? Yes X X X X X X X No What is this point classification? True Minor X X X X X X Synthetic Minor X What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what X Title V X PSD NA NSR X MACT programs? Is this a modification to an existing Yes X No permit? 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? 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.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12—Regulatory Review Regulation 1 - Particulate Smoke Carbon Monoxide and Sulfur Dioxide Page 6 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 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 ll.D.3.a) 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 005 nonattainment or attainment/maintenance areas. This source is not located in the 8-hour ozone nonattainment area, therefore is not subject to RACT requirements. However, operator is using 0.6 saturation factor(submerged loading, dedicated normal service) which does satisfy RACT requirements. Regulation 6- New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 001,002,003 This source in not subject to this section because each individual tank has a capacity less than 471 bbl. 005 No applicable subpart. This facility is not a bulk gasoline terminal_ 007 NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. This source is not subject to this section because it is not a natural gas processing plant. Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS 001, 002, (Applicant is not subject to the emission control requirements for condensate tanks 003 since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since the tanks are not condensate tanks) 005 No sections apply. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. Regulation 8— Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution This source is not subject to MACT EEEE because it is located at a "production field 001, 005 facility" as defined in 40 CFR 63.761 (located upstream of the natural gas processing plant). MACT HH: 001, 007 This source is not subject to MACT HH because it is not located at a major source of HAP. Page 7 Section 13—Aerometric Information Retrieval System Coding Information Process Emission Pollutant/ Fugitive Control Point Process Description Factor CAS# (Y/N) Emission Factor Source (%) 3.19 E&P Tanks Run lb/1000 gal VOC No (converted to lb/1000 gal) 95 0.0204 Benzene/ E&P Tanks Run lb/1000 gal 71432 No (converted to lb/1000 gal) 95 0.0183 Toluene/ No E&P Tanks Run 95 lb/1000 gal 108883 (converted to lb/1000 gal) 0.0004 Ethylbenzene No E&P Tanks Run 95 lb/1000 gal /100414 (converted to lb/1000 gal) 01 E&P Crude Oil 0.0070 Xylene No E&P Tanks Run 95 001 Storage Tanks lb/1000 gal /1130207 (converted to lb/1000 gal) 0.1383 n-Hexane No E&P Tanks Run 95 lb/1000 gal /110543 (converted to lb/1000 gal) 0.0113 2,2,4 TMP E&P Tanks Run lb/1000 gal /540841 No (converted to lb/1000 gal) 95 0.068 NOx No AP42 Tables 13.5-1&2 NA Ib/MMBtu 0.370 CO No AP42 Tables 13.5-1&2 NA lb/MMBtu SCC 40400312—Fixed Roof Tank, Crude Oil,working+breathing+flashing losses Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (Y/N) Emission Factor Source (%) 6.238 lb/1000 gal VOC No CDPHE PS Memo 09-02 95 throughput Produced Water 0.167 Benzene/ 01 Storage Tanks lb/1000 gal 71432 No CDPHE PS Memo 09-02 95 002 9 throughput 0.524 n-Hexane lb/1000 gal /110543 No CDPHE PS Memo 09-02 95 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 __(%)___ 33606.48 VOC No Engineering Calculation NA lb/mmscf 74.88 Benzene/ No Engineering Calculation NA lb/mmscf 71432 56.54 Toluene/ No Engineering Calculation NA Emergency lb/mmscf 108883 01 Storage Tank 9.53 Ethylbenzene No Engineering Calculation NA 003 for gas venting lb/mmscf /100414 23.51 Xylene No Engineering Calculation NA lb/mmscf /1130207 459.34 n-Hexane No Engineering Calculation NA lb/mmscf /110543 0.87 2,2,4 TMP No Engineering Calculation NA lb/mmscf /540841 SCC 31000299— Natural Gas Production: Other not classified Point Process Process Emission Pollutant/ Fugitive Control Description Factor CAS# (Y/N) Emission Factor Source (%) 33606.48 VOC No Engineering Calculation 95 lb/mmscf 74.88 Benzene/ No Engineering Calculation 95 lb/mmscf 71432 004 01 Flare 56.54 lb Toluene/ No Engineering Calculation 95 mmscf 108883 9.53 Ethylbenzene No Engineering Calculation 95 lb/mmscf /100414 23.51 Xylene No Engineering Calculation 95 lb/mmscf /1130207 Page 8 459.34 n-Hexane No Engineering Calculation 95 lb/mmscf /110543 0.87 2,2,4 TMP No Engineering Calculation 95 lb/mmscf /540841 0.068 NOx No AP42 Table 13.5-1 NA lb/MMBtu 0.370 CO No AP42 Table 13.5-1 NA lb/MMBtu SCC 31000205—Flares (at gas production facility) Point Process Process Emission Pollutant/ Fugitive Emission Factor Source Control Description Factor CAS# (YM) (%) 2.47 VOC No AP-42 Ch 5.2 NA lb/1000 gal 0.017 Benzene/ No Engineering Calculation NA lb/1000 gal 71432 0.054 Toluene/ No Engineering Calculation NA Crude Oil and lb/1000 gal 108883 01 Produced Water 0.004 Ethylbenzene No Engineering Calculation NA 005 Loadout lb/1000 gal /100414 0.072 Xylene No Engineering Calculation NA lb/1000 gal /1130207 0.099 n-Hexane No Engineering Calculation NA lb/1000 gal /110543 0.021 2,2,4 TMP No Engineering Calculation NA lb/1000 gal /540841 SCC 40600132: Crude Oil: Submerged Loading (Normal Service) Use if S = 0.6 Process Emission Pollutant/ Fugitive Control Point Process Emission Factor Source Description Factor CAS# (Y/N) (%) 0.358 VOC No AP-42 Table 3.2-3 57 lb/MMBtu 2.210 NOx No AP-42 Table 3.2-3 89 lb/MMBtu 3.72 CO No AP-42 Table 3.2-3 87 lb/MMBtu 01 4SRB RICE 0.0205 Formaldehyde/ No AP-42 Table 3.2-3 50 006 lb/MMBtu 50000 0.00279 Acetaldehyde/ No AP-42 Table 3.2-3 50 lb/MMBtu 75070 0.00263 Acrlolein/1070 No AP-42 Table 3.2-3 50 lb/MMBtu 28 0.00158 Benzene/7143 No AP-42 Table 3.2-3 50 lb/MMBtu 2 SCC 20200253: 4-cycle rich burn Pollutant/ Fugitive Control Point Process Process Description CAS# (Y/N) Emission Factor Source (%) EPA-453/R-95-017,Table 01 Fugitive VOC Leak Emissions VOC Yes 2NA 007 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections,seals, drains) Section 14— Miscellaneous Application Notes AIRS Point 001 Crude Oil Storage Tanks EOG has elected not to exercise the categorical exemption of Reg 3, Part B, Section II.D.1.n (crude oil storage tanks with capacity of 40,000 gallons or less), and to accept federally enforceable emissions limits and control requirements, in order to avoid being classified as a major facility and subject to Title V Operating Permit requirements. This source is not located in the 8-hour ozone non-attainment area. Therefore, the provisions of Regulation 7, Section XII do not apply to this source. Page 9 AIRS Point 002 Produced Water Storage Tanks EOG has elected not to exercise the categorical exemption of Reg 3, Part B, Section II.D.1.m (oil production wastewater containing less than one percent by volume crude oil on an annual average), and to accept federally enforceable emissions limits and control requirements, in order to avoid being classified as a major facility and subject to Title V Operating Permit requirements. AIRS Point 003 Emergency Tank for Vented Gas Estimated emissions for this source are based on three (3) upset events per year lasting 12 hours each and weight fractions from a representative sales gas analysis. Emissions: (scf vented/hr)*(MW of gas)*(weight fraction of constituent)*(1 lb-mol/379.4 scf) = lb/hr Ib/hr*(12hrs/event)*(3 events/yr)*(1 ton/20001b) =TPY VOC = (10,625scf/hr)(27.61 Ib/Ibmol)(0.4618)(1 lb-mol/379.4 scf) = 357.07 lb/hr 357.071b/hr(12hrs/event)(3 events/yr) = 12,854.48 lb/yr= 6.43 TPY Benzene = (10,625scf/hr)(27.61 Ib/Ibmol)(0.001029)(1 lb-mol/379.4 scf) = 0.796 lb/hr 0.796 Ib/hr(12hrs/event)(3 events/yr) = 28.64 lb/yr {28.7 on source calc sheet} Toulene = (10,625scf/hr)(27.61 Ib/Ibmol)(0.000777)(1 lb-mol/379.4 scf) = 0.601 lb/hr 0.601 lb/hr(12hrs/event)(3 events/yr) = 21.63 lb/yr Ethylbenzene= (10,625scf/hr)(27.61 Ib/Ibmol)(0.000131)(1 lb-mol/379.4 scf) = 0.101 lb/hr 0.101 Ib/hr(12hrs/event)(3 events/yr) = 3.646 lb/yr Xylene = (10,625scf/hr)(27.61 Ib/Ibmol)(0.000323)(1 lb-mol/379.4 scf) = 0.250 lb/hr 0.250 Ib/hr(12hrs/event)(3 events/yr) = 8.99 lb/yr n-Hexane = (10,625scf/hr)(27.61 Ib/Ibmol)(0.006312)(1 lb-mol/379.4 scf) =4.881 lb/hr 4.881 Ib/hr(12hrs/event)(3 events/yr) = 175.80 lb/yr 2,2,4 TMP = (10,625scf/hr)(27.61 Ib/Ibmol)(0.000012)(1 lb-mol/379.4 scf) = 0.009 lb/hr 0.009 Ib/hr(12hrs/event)(3 events/yr) = 0.33 lb/yr Emissions factors: (lb/yr)/(0.3825MMscf/yr) = EF(lb/MMscf) VOC = (12,854.48 lb/yr)/(0.3825MMscf/yr) = 33,606.48 lb/MMscf vented Benzene = (28.64 lb/yr)/(0.3825MMscf/yr) = 74.88 lb/MMscf vented Tolelene = (21.63 lb/yr)/(0.3825MMscf/yr) = 56.54 lb MMscf vented Ethylbenzene = (3.646 lb/yr)/(0.3825MMscf/yr) = 9.53 lb/MMscf vented Xylene = (8.99 lb/yr)/(0.3825MMscf/yr) =23.51 lb/MMscf vented n-Hexane =O75.80 lb/yr)/(0.3825MMscf/yr) = 459.34 lb/mmscf vented 2,2,4 TMP = (0.33 Ib/yr)/(0.3825MMscf/yr) = 0.87 Ib/mmscf vented Page 10 AIRS Point 004 Tornado Flare Estimated VOC and HAPs emissions factors for this source are based on weight fractions from a representative sales gas analysis. Calculated emissions are slightly different than those provided on APEN due to rounding differences, however, APEN reported emissions were more conservative in all cases except for Ethylbenzene, where the estimates differed by only one pound. APEN reported emissions were used in PA and permit. Emissions factors: (lb/yr)/(93.075MMscf/yr) = EF(lb/MMscf) VOC = (3,127,923.00 lb/yr)/(93.075MMscf/yr) = 33,606.48 lb/MMscf Benzene = (6969.75 lb/yr)/(93.075MMscf/yr) = 74.88 lb/MMscf Tolelene = (5262.88 lb/yr)/(93.075MMscf/yr) = 56.54 lb/MMscf Ethylbenzene = (887.31 Ib/yr)/(93.075MMscf/yr) = 9.53 lb/MMscf Xylene = (2187.79 lb/yr)/(93.075MMscf/yr) = 23.51 lb/MMscf n-Hexane = (42,753.25 Ib/yr)/(93.075MMscf/yr) =459.34 lb/MMscf 2,2,4 TMP = (81.28 lb/yr)/(93.075MMscf/yr) = 0.87 lb/MMscf Uncontrolled Emissions: (scf vented/hr)*(MW of gas)*(weight fraction of constituentr(1 Ibmol/379.4 scf)= lb/hr lb/hr*(8760hrs/yr)*(1 ton/20001b) = TPY VOC = (10,6258cf/hr)(27.61 Ib/Ibmol)(0.4618)(1 Ibmol/379.4 scf) = 357.069 lb/hr 357.069 Ib/hr*(8760hrs/yr) = 3,127,923.00 lb/yr= 1563.96 TPY {1565.2 on APEN) Benzene = (10,625scf/hr)(27.61)( 0.001029)(1 Ibmol/379.4 scf) = 0.796 lb/hr 0.796 lb/hr(8760hrs/yr) =6969.75 lb/yr {6981.4 on source calc sheet) Tolelene = (10,625scf/hr)(27.61)( 0.000777)0 Ibmol/379.4 scf) = 0.601 lb/hr 0.601 Ib/hr(8760hrs/yr) = 5262.88 lb/yr {5,271.5 on source calc sheet) Ethylbenzene = (10,625scf/hr)(27.61)( 0.000131)(1 lbmol/379.4 scf) = 0.101 lb/hr 0.101 Ib/hr(8760hrs/yr) = 887.31 lb/yr {886.3 on source calc sheet) Xylene = (10,625scf/hr)(27.61)( 0.000323)0 Ibmol/379.4 scf) = 0.250 lb/hr 0.250 Ib/hr(8760hrs/yr) =2187.79 lb/yr {2189.6 on source calc sheet) n-Hexane = (10,625scf/hr)(27.61)( 0.006312)0 lbmol/379.4 scf) =4.881 lb/hr 4.881 lb/hr(8760hrs/yr) =42,753.25 lb/yr {42,798.8 on source calc sheet} 2,2,4 TMP = (10,625scf/hr)(27.61)( 0.000012)(1 lbmol/379.4 scf) = 0.009 lb/hr 0.009 Ib/hr(8760hrs/yr) = 81.28 lb/yr {84.1 on source calc sheet) Emissions factors for NOx and CO are from AP42 Tables 13.5-1&2. SO2 emissions are based on AP42 Table 1.4-2 and 100% conversion. PM10 and PM2.5 emissions are based on AP42 Table 13.5-1 (lightly smoking flares) EFs: NOx = 0.068 lb/MMBtu, CO = 0.370 lb/MMBtu, SO2 = 0.00037 lb/MMBtu, PM10 and PM2.5 = 40pg/L Emissions: =(10,625scf/hr)(1,549Btu/scf)(MMBtu/E6Btu)(EF)(8760hr/yr) = lb/yr NOx=(10,625scf/hr)(1,549Btu/scf)(MMBtu/E6Btu)( 0.068 lb/MMBtu)(8760hr/yr) = 9803.78 lb/yr= 4.90TPY CO=(10,625scf/hr)(1,549Btu/scf)(MMBtu/E6Btu)( 0.370 lb/MMBtu)(8760hr/yr) = 53344.1 lb/yr= 26.67 5O2=(10,625scf/hr)(1,549Btu/scf)(MMBtu/E6Btu)( 0.00037 lb/MMBtu)(8760hr/yr) = 53.341b/yr= 0.03TPY PM10=(10,625scf/hr)(8760hr/yr)(28.32Uscf)(40pg/L)(1g/E6pg)(11b/454g) =232.241b/yr= 0.116TPY{1.2 TPY on calc sheet) PM2.5=(10,625scf/hr)(8760hr/yr)(28.32Uscf)(40pg/L)(1g/E6pg)(11b/454g) = 232.241b/yr= 0.116TPY{1.2 TPY on calc sheet) Page 11 AIRS Point 005 Truck Condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 5.18 Psia Based on EPA TANKs run M 33.43 Lb/lb-mole Based on EPA TANKs run T 524 Deg R Based on source's knowledge of bulk liquid temperature L 2.47 Lb/10^ gal This value is used to calculate annual emissions. 1.04E-01 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 5.18 Psia, M 33.43 lb/lb-mole T 524 deg. R L 2.471b/10^3 gal 1.04E-01 lb/bbl Annual requested Throughput 7665000ga1/yr Annual requested VOC emissions 189371b/yr 9.47tpy AIRS Point 006 4SRB Reciprocating Internal Combustion Engine Source relocated to Colorado on 04/27/2011, subject to Reg 7 requirements. A (slightly) rounded down annual fuel consumption was requested compared to the PTE, however, operators emissions estimates for the engine were slightly more conservative because they used the HHV fuel value as opposed to the LHV fuel value. AIRS Point 007 Fugitive Component Leak Emissions An APEN was submitted (Feb 14, 2012) for the fugitive emissions associated with this facility after a mistake was noted in the initial calculations and revised calculations indicated that fugitive VOC emissions were above the APEN reporting threshold. A component hard count will be required in the permit. The weight fraction for VOC and HAP components in gas production, light oil and heavy oil service are from Oil and Gas Production Facilities Chapter 6 Section 2 Permitting Guidance, Fugitive Emissions (pg 71-81) from WDEQ, Air Quality Division. The weight fraction for VOC and HAP components for water/oil service are from Gas Research Institute's Technical Reference Manual for GRI-HAPcalc. Page 12 N ri Y V O V O G O T e E o 0o vi ° - c E z u v M M M c i ❑ a N O ` 3 >. N Q .a E. C b b b ` y a O O l CV O. 6 v ., �. E N a o rl Y . m L m d F . > m \1�'•i. q W > A Y y a en en m O O o .. 0 C o O �' K u e c H 0.. IT; .5 = .l, n a Eta u? o o a.. a y .4 T. (N T v G _ a Y ' w p z o. W - i m G O a y7—�� v O 00 V N W W R a h u o o .E a 4:1' Ltd E/C V/`ivA yIF.; u 14,1 E TA� a A in i P. Q V. A € O4 �( 0 ' c . Y I ' . / =i t r4 C N 6 d I ♦.. cJ 4) n u m w a .. O o .. / a 4 Q v y " ti m ne r ICI " v c 2 a 3' w Y , IN2 3 u s x E a - v v o co CI Y E `a u u — m �` o.. �, a s v ea Y i. 2 a y = u.. 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CC ON - ` AS •� . � o E O 5 .e _3,E car 0 u P O. u 2 ._ 0 4 v I;, C .7 0 �,o w 9 .c r 5 E N. U C in 0 F ..-1 W e 0 I ❑qm I v ` c y a h I Hu ¢ 4 G a Z N m y a, 0 9 0 - T n c 0 0 v v v a. I o o u E . cc o E a c e u e or a e sr a c y W rn s e W N d = X '° E o N❑ 0 ,peU c ba a �, E c u c a v z u e Wer 0 m a o `° — ti p P. W F C '� ,:t ›-. ^ 0 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) Reason for MEN Submittal(Check all that apply) AIRS ID#': 12 Z/Tit 4/1)&1 ❑ APEN update only4 -. ❑ New or prbviously unreported battery ❑ Modification to existing source' ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GPOI `EiC ❑ Synthetic minor facility &cancellation request for individual permit°: ❑ Located in the 8-hr Ozone Control Area' N Application for or Modification of an individual permit . '. C ❑ Registered under general permit no.GPO] ❑ Administrative permit amendment' :,,a%4 / . ❑ Permitted under individual permit: 11 w E 311 t2 ❑ Other: `'t `) For individual permit applications,check if you want': ❑A copy of the preliminary analysis conducted by the Division`C'`- ❑To review a draft of the permit prior to issuance Company Name9: EOG Resources,Inc. OGCC Operator#: 27742 Mailing Address10: 600 17°i 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 Name I: Lion Creek 7-24H Number of tanks: 6 Location"(QQ Sec.Twp.Range.): SWSE Sec 24,71 IN,R64W County: Weld Total tank capacity[bbl]: 2,400(400 ea) Calendar year for which"Actual"data applies': 2011 Year(s)tank(s)were placed in service": 2011 Control Description': Cimarron Smokeless Combustor(vapor combustion unit[VCU1) Control Efficiency16: 95% Condensate Throughputs'[bbl/year] Requested": 109,500 Maximum for PTE calculation19: 131,400 Actual": 109,500 While Controls Operationalz' 109,500 Other equipment at facility": VCU,flare,heater treater,generator engine,line heater,produced 1320 tank,emergency blow down tank Comments: Due to the low gravity of the oil,the tanks do not qualify for GPO]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. 0 Check if site-specific emission factors provided to calculate emissions'. Emission Factor Battery Requested Emissions" Actual Emissions" Pollutant" fib/bbl] PTE25 Uncontrolled26 Controlled=' Uncontrolled26 Controlled" VOC[tons/year] 0.1341 8.8 N/A N/A 7.3 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] O.OWi?d6 A66 94.0 4.7 n-Hexane[lbs/year] b.60j 9 04' 636.0 31.8 Wells serviced by this tank or tank battery]° API#: 05-123-32697-00 Name: Lion Creek 7-24H N Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well H, API#: Name: ❑Newly Reported Well N w API#: Name ❑Newly Reported Well I w API#: Name: ❑Newly Reported Well c:,': w API#: Name: ❑Newly Reported Well 4-13 o The signature below indicates that I have Imowledge of the facts herein set forth and that the same are true,accurate,and complete to the be°st'of ?Mudge and belief. If this is a registration for coverage under general permit GPOI,I further certify that this source is and will be operated y full plian .the h condition f general permit GPOI. hrt Cr ��..,1J (On./C,7 7 i/ s Tv' i e o egally Authorized erson(not a vendor or consultant) Dat 1:5 :1 o David Long Division Environmental Manager r-k r Type or Print Name of Person Signing Above Official Tide w Co Submit this form,along with$152.90 for each Colorado Department of Public Health and Environm% information call: i o filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI (303)692-3150'i=iI $250 General Permit fee for each new GP 4300 Cherry Creek Drive South 259490 o registration to: Denver,CO 80246-1530 FORM APCD-205 Page I of 2 EOG LC 7-2411 FormAPCD-205-E&PCondensateTankAPEN.docx N t\f u o e a E o -' _ r' E e u o m vi 5 0 ca 0 c a y L n h r- - E I u e L E C A ❑ 0 e W0.� m Y z O Y N N N C y 0 col % O O 0. G p. 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V /� ,?.?7,,-?_- F v �`l 4 : rl -,-,, ❑ N N N oil p y F-r V F O w^�'.. v i 8I tlC u pite iyr N O N a .car"'I W C p' ( m l_ nV) CO O o 0 0 , y Q 1 4 ti?, i,i'i-_pi 7.,„7.: — :le # .�. < (�.71 7, IIKIL I-4421k r i2 > ® ❑ ='.p - o bl ..r E T up m '' !`� 1' ® n ItvLm u u E a: a c L L p op. 'v - W o> a d a a d a d v _ a�'. •^_ E E v > N9 V.' Q Cl L L L v ❑ � rJ" ,d o I ' c4 t4 C4 cG 7. W W' U °' T ra x � = _ N V r a ' G tU Z Z Z CO Z Z Z m ,�a `� 9 x v i• Q-i `lP.' W y m Li ' y g e ' no o, Ti,y �1 o o. I :F W c a .a c v �a' at w' C L°,o 0 .t C t-,....c...1,0:,yA N O i a p H O 9 9 ° O d as ,11:+r-e.- , ., �, w z $' ,."‘4,..,', F a y Z O> U € v d m , ; .. v A STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT c %I AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 +W2* �+1876 CONSTRUCTION PERMIT PERMIT NO: 1 1 WE31 10 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Natural gas exploration/production facility, known as the Lion Creek 7-24H located at Section 24, Township 11N, Range 64W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Crude Oil Six (6) 400 BBL fixed roof atmospheric storage tanks used to store Storage 001 crude oil. Emissions from these tanks are controlled by a Cimarron Tank smokeless combustor with 95% control efficiency. One (1) 400 BBL fixed roof atmospheric storage tank used to store PW Tank 002 produced water. Emissions from this tank are controlled by a Cimarron smokeless combustor with 95% control efficiency. One (1) 400 BBL emergency tank (Manufacturer: Connor, Model: ET #4431 003 EOG #4431, Serial #11-022) 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) Tornado flare (Manufacturer: Tornado, Model: 40' Flare Flare 004 Stack, Serial#10670-5) for control of gas production stream from separator. Truck 005 Truck loadout of crude oil and produced water. Loadout One (1) International, Model NG466TA, Serial Number 674774-65, natural gas-fired, naturally aspirated, 4SRB reciprocating internal Generator RICE 006 combustion engine, site rated at 134 horsepower at 1800 RPM. Engine This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for electricity generation. Fugitive 007 Equipment leaks (fugitive VOCs) AIRS ID: 123/9314/001-007 Page 1 of 22 Condensate Tank Version 2009-1 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 Point 006 may be replaced with another engine in accordance with the temporary engine replacement provision or with another International Model NG466TA 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, II.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. 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: AIRS ID: 123/9314/001-007 Page 2 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 • Four 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, V0C CO Crude Oil 001 - 0.4 - Point Storage Tank PW Tank 002 - 0.5 - Point ET#4431 003 - 6.4 - Point Flare 004 4.9 78.3 26.7 Point Truck Loadout 005 - 9.5 - Point Generator 006 1.3 0.9 2.6 Point RICE Engine 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. 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 001: This emissions point shall be configured with a vapor combustion unit (VCU) capable of reducing uncontrolled emissions of VOC from the crude oil tanks to the emission levels listed in Condition 7 of this section. 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 002: This emissions point shall be configured with a vapor combustion (VCU) unit capable of reducing uncontrolled emissions of VOC from the produced water tanks to the emission levels listed in Condition 7 of this section. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation • No.3, Part B, Section III.E.) AIRS ID: 123/9314/001-007 Page 3 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 10. Point 004: This emissions point is a separator controlled by an open-flame flare. The flare shall reduce emissions of VOC to the emissions levels listed in Condition 7 of this section. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Point 006:This engine shall be equipped with a non-selective catalytic reduction(NSCR) system and air-fuel ratio control. The NSCR shall reduce uncontrolled emissions of NOx, VOC and CO from the unit to the emission levels listed in Condition 7 of this section. 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 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 Facility AIRS Equipment Point Process Parameter Annual Limit ID Crude Oil Storage 001 Crude Oil throughput 109,500 BBL/yr Tanks PW Tank 002 Produced water throughput 73,000 BBL/yr ET#4431 003 Natural gas vented to atmosphere 382,500 SCF/yr through emergency tank Flare 004 Natural gas flaring 93.075 MMscf/yr Truck 005 Crude oil and produced water loading 182,500 BBL/yr Loadout Generator 006 Consumption of natural gas as a fuel 7.8 MMscf/yr RICE Engine Compliance with the yearly 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 each actual monthly process rate and keep a compliance record on site or at a local field office with site responsibility, for Division review. 14. Point 002: 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. AIRS ID: 123/9314/001-007 Page 4 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 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. Points 001,002, and 004: 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. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 19. Point 005: Crude oil and produced water loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 20. Point 006: 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: Maximum Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 OPERATING & MAINTENANCE REQUIREMENTS 21. Points 001, 004, 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 002: AIRS ID: 123/9314/001-007 Page 5 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 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 reasonable 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 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 001: 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 AIRS ID: 123/9314/001-007 Page 6 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 and used to demonstrate compliance with the emissions factors chosen for this emissions point. 24. Points 003 and 004: The operator shall complete an initial site specific extended gas 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 emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as pad 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 r in the site-specific gas analysis: x ib bansarna = benzene wt,frac.* lb mvi, * �f YV as I ib * Ya6 sal Werscf 379.3 scf 9 lb r+ioL 1MMscf. 25. Point 004: 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.V) 26. Point 006: A source initial compliance test shall be conducted 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 27. Point 007: Within one hundred and eighty days (180) after issuance of this 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 this 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. AIRS ID: 123/9314/001-007 Page 7 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 Periodic Testing Requirements 29. Point 006: 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 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 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. f. Point 006: 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) AIRS ID: 123/9314/001-007 Page 8 of 22 • EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 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 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. AIRS ID: 123/9314/001-007 Page 9 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 By: Joshua Jones Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Facility-wide permit for new synthetic minor E&P facility. AIRS ID: 123/9314/001-007 Page 10 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it 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.cd phe.state.co.us/regulations/airregs/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 94 YES 4.7 Toluene 108883 C 84 NO 4.2 Ethylbenzene 100414 C 2 NO 0.1 001 Xylene 1330207 C 32 NO 1.6 n-Hexane 110543 C 636 .NO 31.8 2,2,4- 110543 C 52 NO 2.6 Trimethylpentane Benzene 71432 A 511 YES 25.6 002 Hexane 110543 C 1606 YES 80.3 Benzene 71432 A 28.7 NO NA Toluene 108883 C 21.6 NO NA 003 Ethylbenzene 100414 C 3.6 NO NA Xylene 1330207 C 9.0 NO NA n-Hexane 110543 C 175.8 NO NA Benzene 71432 A 6981.4 YES 349.1 Toluene 108883 C 5271.5 YES 263.6 Ethylbenzene 100414 C 886.3 NO 44.3 004 Xylene 1330207 C 2189.6 YES 109.5 n-Hexane 110543 C 42798.8 YES 2139.9 2,2,4- 110543 C 84.1 NO 4.21 Trimethylpentane AIRS ID: 123/9314/001-007 Page 11 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 Benzene 71432 A 127.0 Yes NA Toluene 108883 C 415.7 No NA Ethylbenzene 100414 C 30.6 No NA 005 Xylene 1330207 C 553.1 No NA n-Hexane 110543 C 757.8 No NA 2,2,4- 110543 C 160.7 No NA Trimethylpentane Formaldehyde 50000 A 248 Yes 124 Methanol 67561 C 37 No 19 Acetaldehyde 75070 A 34 No 17 006 Acrolein 107028 A 32 No 16 Benzene 71432 A 19 No 9.6 1,3-Butadiene 106990 A 8 No 4 Toluene 108883 C 7 No 4 Benzene 71432 A 7.5 No NA Toluene 108883 C 12.2 No NA 007 Ethylbenzene 100414 C 1.7 No NA Xylene 1330207 C 4.5 No NA n-Hexane 110543 C 252.0 No NA 4) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS# Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled VOC 0.1341 lb/BBL 0.0067 lb/BBL E&P Tanks 71432 Benzene 8.6x10'"° lb/BBL 4.3x10-°s lb/BBL E&P Tanks 108883 Toluene 7.7x10'" lb/BBL 3.8x10-"' lb/BBL E&P Tanks _ 100414 Ethylbenzene 1.8x10-"' lb/BBL 9.1x10 ' lb/BBL E&P Tanks 1330207 Xylene 2.9x10` lb/BBL 1.5x10"5 lb/BBL E&P Tanks 110543 n-Hexane 5.8x10" lb/BBL 2.9x10-1) lb/BBL E&P Tanks 540841 2,2,4-TMP 4.7x10-"° lb/BBL 2.4x10-"' lb/BBL E&P Tanks Note: The controlled emissions factors for point 001 are based on the VCU control efficiency of 95%. These emission factors were developed using a pressurized liquids analysis from the Critter Creek 2-03H well. Point 002: CAS # Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled _ VOC 0.262 lb/BBL 0.0131 lb/BBL CDPHE default AIRS ID: 123/9314/001-007 Page 12 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 CAS# Pollutant Emission Factors Emission Factors Source Uncontrolled Controlled 71432 Benzene 0.007 lb/BBL 0.0004 lb/BBL CDPHE default 110543 n-Hexane 0.022 lb/BBL 0.0011 lb/BBL CDPHE default Note: The controlled emissions factors for point 002 are based on the VCU control efficiency of 95%. Point 003: Emission Factors Natural Gas CAS # Pollutant Uncontrolled Composition Source (Weight%) VOC 33,606.48 lb/MMscf 46.18 Engineering Calculation Engineering 71432 Benzene 74.88 lb/MMscf 0.10 Calculation Engineering 108883 Toluene 56.54 lb/MMscf 0.08 Calculation Engineering 100414 Ethylbenzene 9.53 lb/MMscf 0.01 Calculation Engineering 1330207 Xylenes 23.51 lb/MMscf 0.03 Calculation Engineering 110543 n-hexane 459.34 lb/MMscf - 0.63 Calculation Note: 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 10,625.0 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). Point 004: Natural Gas Emission Emission Composition Factors Factors CAS# Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf lb/MMscf natural gas natural gas vented vented AP-42, Table NOx NA 105.33 105.33 13.5-1, 1549 Btu/scf AP-42, Table CO NA 573.13 573.13 13.5-1, 1549 Btu/scf Engineering VOC 46.18 33,606.48 1680.3 Calculation Engineering 71432 Benzene 0.1029 74.88 3.74 Calculation AIRS ID: 123/9314/001-OO7 Page 13 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf lb/MMscf natural gas natural gas vented vented 108883 Toluene 0.0777 56.54 2.83 Engineering Calculation 100414 Ethylbenzene 0.0131 9.53 0.48 Engineering Calculation 1330207 Xylenes 0.0323 23.51 1.18 Engineering Calculation 110543 n-Hexane 0.6312 459.34 22.97 Engineering Calculation 540841 2,2,4-TMP 0.0012 0.87 0.04 Engineering Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 10, 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 005: Emission Factors- Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.104 lb/BBL AP-42 71432 Benzene 0.0007 lb/BBL AP-42 108883 Toluene 0.0023 lb/BBL AP-42 100414 Ethylbenzene 0.0002 lb/BBL AP-42 1330207 Xylene 0.0030 lb/BBL AP-42 110543 n-Hexane 0.0042 lb/BBL AP-42 540841 2,2,4-TMP 0.0009 Ib/BBL 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 M (vapor molecular weight) = 33.43 lb/lb-mol T (temperature of liquid loaded) = 524 °R Note: The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP determined in the pressurized oil analysis by the VOC emission factor. Point 006: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 2.21 9.42 0.46907 2 AIRS ID: 123/9314/001-007 Page 14 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 Emission Factors - Emission Factors- Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr CO 3.72 15.86 0.9381 4 VOC 0.385 1.64 0.2345 1 50000 Formaldehyde 0.0205 0.0874 0.01025 0.0437 67561 Methanol 0.00306 0.0130 0.0015 0.0065 75070 Acetaldehyde 0.00279 0.0119 0.0014 0.0059 107028 Acrolein 0.00263 0.0112 0.0013 0.0056 71432 Benzene 0.00158 0.0067 0.0008 0.0034 106990 1,3-Butadiene 0.000663 0.0028 0.0003 0.0014 108883 Toluene 0.000558 0.0024 0.0003 0.0012 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9400 Btu/hp-hr, a site- rated horsepower value of 134, and a fuel heat value of 1413 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx AP-42 Manufacturer CO AP-42 Manufacturer VOC AP-42 Manufacturer 50000 Formaldehyde AP-42 Manufacturer Point 007: Water/Oil Component Gas Service Heavy Oil Light 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% .12% Toluene Content(wt%) 0.039% --- 0.075% .032% Ethylbenzene Content(wt%) 0.002% --- 0.017% .001% Xylene Content(wt%) 0.01% --- 0.036% .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): Water/Oil Component Gas Service Heavy Oil Light 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 AIRS ID: 123/9314/001-007 Page 15 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 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 according to the dates in the table below. A revised APEN shall be submitted no later than 30 days before the five-year term expires. AIRS Point APEN Expiration 001-006 August 3, 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 MACT HH Area Source Requirements: Not Applicable MACT ZZZZ Area Source Requirements: Not Applicable 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.f2Doaccess.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 AIRS ID: 123/9314/001-007 Page 16 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 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 8) 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/oilgaspermitting.html AIRS ID: 123/9314/001-007 Page 17 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it 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: 123/9314/001-007 Page 18 of 22 EOG Resources, Inc. olor- Depa en f li Health and Environment Permit No. 11WE3110 4 it Pollution Control Division Issuance 1 2.1.2 The permittee may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the permittee is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The permittee shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The permittee may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The permittee shall measure nitrogen oxide(NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer). Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9314/001-007 Page 19 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it Pollution Control Division Issuance 1 For comparison with a short-term limit that is either input based (Ib/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 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. AIRS ID: 123/9314/001-007 Page 20 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it 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 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, §1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: 123/9314/001-007 Page 21 of 22 EOG Resources, Inc. olor Depa en f li Health and Environment Permit No. 11 WE3110 it 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 Z777. 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: 123/9314/001-007 Page 22 of 22 Hello