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Home My WebLink About20131794.tiffSTATE OF COLORADO John W. Hickenlooper, Governor Christopher E. Urbina, MD, MPH Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Laboratory Services Division Denver, Colorado 80246-1530 8100 Lowry Blvd. Phone (303) 692-2000 Denver, Colorado 80230-6928 Located in Glendale, Colorado (303) 692-3090 http://www.cdphe.state.co.us Weld County Clerk & Recorder 1402 N 17th Ave Greeley, CO 80631 July 2, 2013 Dear Sir or Madam: RECEIVED JUL 0 9 2(493 WELD COUNTY COMMISSIONERS Colorado Department of Public Health and Environment On July 5, 2013, the Air Pollution Control Division will publish a public notice for EOG Resources — Critter Creek 34-16H, in the The Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Pleasesend any comment regarding this public notice to the address below. Colorado Dept. of Public Health & Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure -RG leguittiti 11(5 113 CV; PL WI -,PA) 2013-1794 I STATE OF COLORADO John W. Hickenlooper, Governor Christopher E. Urbina, MD, MPH Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Denver, Colorado 80246-1530 Phone (303) 692-2000 Located in Glendale, Colorado http://www.cdphe.state.co.us Laboratory Services Division 8100 Lowry Blvd. Denver, Colorado 80230-6928 (303) 692-3090 Website Title: EOG Resources — Critter Creek 34-16H — Weld County Released To: The Greeley Tribune On: July 2, 2013 Published: July 5, 2013 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Colorado Department of Public Health and Environment Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: • Applicant: EOG Resources Facility: Critter Creek 34-16H Natural gas production facility NWNE Section 16 of T11N, R63W Weld County The proposed project or activity is as follows: The applicant proposes to construct a natural gas production facility The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section 111.C.I.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 11WE3684 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Stuart Siffring Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 11WE3684 Issuance 1 DATE ISSUED: ISSUED TO: EOG Resources, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas production facility, known as Critter Creek 34-16H, located in the NWNE of Section 16, Township 11 North, Range 63 West, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description Crude Oil Storage Tanks 001 Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from these tanks are controlled by a Cimarron smokeless VCU unit with 95% control efficiency. PW Tank 002 One (1) above ground 400 bbl atmospheric produced water storage tank. Emissions from this tank are controlled by a combustor (VCU) with a minimum destruction efficiency of 95%. ET #4830 003 One (1) 400 BBL fixed roof storage tank used to store gas in the event that there is a need to vent the gas rather than flaring. Emissions from this tank are not controlled. Flare 004 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Generator RICE Engine 005 One (1) International, Model NG466TA, Serial Number 674774-85, natural gas -fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 134 horsepower at 1800 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for primary power until electricity can be run to the location. Truck Loadout 006 Truck loadout of crude oil and produced water. Fugitive 007 Equipment leaks (fugitive VOCs) from a natural gas production facility. Point 005 may be replaced with another engine in accordance with the temporary engine replacement provision or with another International Model NG466TA engine in accordance with AIRS ID: 123/9575/999 Page 1 of 20 Condensate Tank Version 2009-1 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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 or activity 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 fora 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, 4, The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: AIRS ID: 123/9575/999 Page 2 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division Facility Equipment ID AIRS Point Tons per Year Emission Type NO, VOC CO Crude Oil Storage Tanks 001 --- 0.2 --- Point PW Tank 002 --- 0.2 --- Point ET #4830 003 --- 12.1 --- Point Flare 004 1.9 30.7 10.5 Point Generator RICE Engine 005 1.3 0.9 2.6 Point Truck Loadout 006 --- 4.7 - Point Fugitive 007 --- 2.4 -- Fugitive See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate limits. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Point 001: This emissions point shall be configured with a combustor. The combustor shall reduce the uncontrolled emissions of VOC to the emission levels listed in this section, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. Point 002: This emissions point shall be configured such that vapors are routed to a combustor (VCU). The VCU shall reduce uncontrolled emissions of VOC to the emission levels listed in this section, 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 004: This emissions point is a separator controlled by a 40' flare stack. The flare shall reduce emissions of VOC to the emission levels listed in this section, 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 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 this section, above. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 11. Point 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 AIRS ID: 123/9575/999 Page 3 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum consumption, processing and/or operational rates as listed below. Monthly records of the actual throughput 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 Equipment ID AIRS Point Process Parameter Annual Limit Crude Oil Storage Tanks 001 Crude oil throughput 54,750 BBL/yr PW Tank 002 Produced water throughput 36,500 BBL/yr ET #4830 003 Natural gas venting to atmosphere 721,875 SCF/yr Flare 004 Natural gas flaring 36.5 MMSCF/yr Generator RICE Engine. 005 Consumption of natural gas as a fuel 7.8 MMscf/yr Truck Loadout 006 Crude oil and produced water loading 91,250 BBL/yr 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 monthly crude oil throughput and keep a compliance record on site or at a local field office with site responsibility, for Division review. 13. 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 14. 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) 15. 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.). 16. 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.). 17. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) AIRS ID: 123/9575/999 Page 4 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 18. Point 005: 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: Note that this condition may not apply if the engine is subject to standards under NSPS or MACTs (see Reg 7 XVII.B.4). Note that there must be an actual emission standard under NSPS/MACT in order for Reg 7 to not apply. Note also that in most cases, the NSPS/MACT standards will be the same as what would be required for Reg. 7: Maximum Engine HP Construction or Relocation Date Emission Standard in g/hp-hr NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and <500HP January 1, 2008 January 1, 2011 2.0 1.0 4.0 2.0 1.0 0.7 ≥500HP July 1, 2007 July 1, 2010 2.0 1.0 4.0 2.0 1.0 0.7 19. Point 006: Crude oil loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 20. Points 001, 004 and 005: 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.) 21. Point 002: 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. AIRS ID: 123/9575/999 Page 5 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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 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 22. 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 and used to demonstrate compliance with the emissions factors chosen for this emissions point. 23. 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 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: AIRS ID: 123/9575/999 Page 6 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division iv oanssne 2b mo:. lb _I ,Vr,lr:cf = benzene wt. frac.* 37S.3 se,' * "WW:ga, ;.banal l66scf hurdscf, 24. Point 004: The owner or operator shall demonstrate compliance with Condition 16 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section I I.A.5). 25. 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. 26. 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. 27. Point 005: A source initial compliance test shall be conducted on emissions point 005 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 Periodic Testing Requirements 28. Point 005: 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 29. 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: AIRS ID: 123/9575/999 Page 7 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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 005: 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. 30. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 31. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 32. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 33. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, AIRS ID: 123/9575/999 Page 8 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 34. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 35. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 36. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 37. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Stuart Siffring Permit Engineer Air Pollution Control Division Permit Histo Issuance Date Description Issuance 1 This Issuance Facility -wide permit for: Crude oil tanks, produced water tank, emergency tank, enclosed flare, Generator RICE, truck loadout, and fugitive emissions. New synthetic minor facility. AIRS ID: 123/9575/999 Page 9 of 20 EOG Resources, Inc. Permit No. 11 WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) 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. 3) 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/requlations/airreqs/1 001 02aqcccomm on p rovisionsreq. pdf. 4) 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. AIRS Point Pollutant CAS # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 001 Benzene 71432 A 46 No 2 n -Hexane 110543 C 312 No 16 002 Benzene 71432 A 256 Yes 13 n -Hexane 110543 C 803 No 40 003 Benzene 71432 A 54 Yes 54 Toluene 108883 C 41 No 41 Ethylbenzene 100414 C 7 No 7 Xylenes 1130207 C 17 No 17 n -Hexane 110543 C 332 No 332 004 Benzene 71432 A 2738 Yes 137 Toluene 108883 C 2067 Yes 103 Ethylbenzene 100414 C 348 No 17 Xylenes 1130207 C 859 No 43 n -Hexane 110543 C 16784 Yes 839 005 Formaldehyde 50000 A 248 Yes 106 Acetaldehyde 75070 A 34 No 14 Acrolein 107028 A 32 No 14 AIRS ID: 123/9575/999 Page 10 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division Benzene 71432 A 37 No 16 006 Benzene 71432 A 63 Yes 63 Toluene 108883 C 208 No 208 Ethylbenzene 100414 C 15 No 15 2,2,4- Trimethylpentane 540841 C 80 No 80 Xylenes 1130207 C 277 No 277 n -Hexane 110543 C 379 No 379 007 Benzene 71432 A 8 No 8 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 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS # Pollutant Emission Factors Uncontrolled Emission Factors 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 0.1319 lb/bbl 0.0066 lb/bbl E&P Tanks 71432 Benzene 0.00084 lb/bbl 0.000042 lb/bbl E&P Tanks 110543 n -hexane 0.0057 lb/bbl 0.00028 lb/bbl E&P Tanks Note: The controlled emissions factors for point 001 are based on the combustor 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 Uncontrolled lb/BBL Produced Water Throughput Emission Factors Controlled lb/BBL Produced Water Throughput Source VOC 0.262 0.0131 PS Memo 09-02 110543 n -Hexane 0.022 0.0011 PS Memo 09-02 71432 Benzene 0.007 0.0004 PS Memo 09-02 Note: The controlled emissions factors for point 002 are based on the combustor control efficiency of 95%. Point 003: CAS # Pollutant AIRS ID: 123/9575/999 Emission Factors Uncontrolled Weight Fraction of Gas (%) Source Page 11 of 20 EOG Resources, Inc. Permit No. 11 WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division Lb/MMscf VOC 33612 lb/MMscf 46.18 Engineering Calculation 71432 Benzene 74.8 lb/MMscf 0.10 Engineering Calculation 108883 Toluene 56.4 lb/MMscf 0.08 Engineering Calculation 100414 Ethylbenzene 9.5 Ib/MMscf 0.01 Engineering a Calculation 1330207 Xylenes 23.41b/MMscf 0.03 Engineering Calculation a 110543 n -hexane 459.3 lb/MMscf 0.63 Engineering Calculation The emission levels in this nermit for this noint 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 20,052.1 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: CAS # Pollutant Weight Fraction of Gas (%) Emission Factors Uncontrolled Emission Factors Controlled Source NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP -42 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP -42 VOC 46.18 33612 lb/MMscf 1680 lb/mmscf Engineering Calculation PM,o 40 ug/l 40 ug/I AP -42, Table 13.5-1 SOx 0.00036 lb/MMBtu 0.00036 lb/MMBtu 0.002 gr/scf 71432 Benzene 0.10 74.8 lb/MMscf 3.7484 lb/mmscf Engineering Calculation 108883 Toluene 0.08 56.4 lb/MMscf 2.8303 lb/mmscf Engineering Calculation 100414 Ethylbenzene 0.01 9.5 lb/MMscf 0.4759 lb/mmscf Engineering Calculation 1330207 Xylenes 0.03 23.4 lb/MMscf 1.1756 lb/mmscf Engineering Calculation 110543 n -hexane 0.63 459.3 lb/MMscf 22.9790 lb/mmscf Engineering Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the analysis of a gas sample collected from the Critter Creek 2-03H well. The controlled VOC and HAP emissions factors for point 004 are based on the flare control efficiency of 95%. Point 005: Emission Factors - Emission Factors — Uncontrolled Controlled CAS Pollutant Ib/MMBtu I _g/bhp-hr Ib/MMBtu I g/bhp-hr AIRS ID: 123/9575/999 Page 12 of 20 EOG Resources, Inc. Permit No. 11 WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division CAS Pollutant Emission Uncontrolled Ib/MMBtu Factors - g/bhp-hr Emission Factors — Controlled lb/MMBtu g/bhp-hr NOx 2.21 9.38 0.243 1 CO 3.72 15.861 0.484 2.0 VOC 0.385 1.64 0.166 0.7 50000 Formaldehyde 0.0205 0.0874 0.0088 0.0376 75070 Acetaldehyde 0.0028 0.0119 0.0012 0.0051 107028 Acrolein 0.0026 0.0112 0.0011 0.0048 71432 Benzene 0.0016 0.0067 0.0007 0.0029 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 Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde AP -42 AP -42 , Point 006: CAS Pollutant Emission Factors lb/BBL loaded - Uncontrolled Source - VOC 0.104 AP -42 71432 Benzene 0.0007 AP -42 108883 ' Toluene 0.0023 AP -42 100414 Ethylbenzene 0.0002 AP -42 1330207 Xylenes 0.0030 AP -42 110543 I n -hexane 0.0042 AP -42 540841 i 2,2,4-TMP 0.0009 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 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 the VOC emission factor. 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 AIRS ID: 123/9575/999 Page 13 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division VOC Content (wt%) 3.5% 100% 29.2% 100% Benzene Content (wt%) 0.023% --- 0.027% 0.12% 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%) 0.336% --- 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): 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. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source VOC PSD Synthetic Minor Source VOC MACT HH Area Source Requirements: Not Applicable MACT ZZZZ Area Source Requirements: Not Applicable 8) 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/ AIRS ID: 123/9575/999 Page 14 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A — Subpart KKKK NSPS Part 60, Appendixes Appendix A — Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A — Subpart Z MACT 63.600-63.1199 Subpart AA — Subpart DDD MACT 63.1200-63.1439 Subpart EEE — Subpart PPP MACT 63.1440-63.6175 Subpart QQQ — Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ — Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX 9) An Oil and Gas Industry Construction Permit Self -Certification Form is included with this permit packet. Please use this form to complete the self -certification requirements as specified in the permit conditions. Further guidance on self -certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilgaspermitting.htnnl AIRS ID: 123/9575/999 Page 15 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 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 owner or operator 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 owner or operator 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 owner or operator 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 owner or operator 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. 2.1.2 The owner or operator 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 AIRS ID: 123/9575/999 Page 16 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division applicable requirements for the replacement engine. Measurement of emissions fromthe 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 permanentreplacement 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 owner or operator 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 owner or operator 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 owner or operator 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 owner or operator 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) as found on the Division's web site at: http://www.colorado.uov/cs/Satellite/CDPHE-AP/CBON/] 251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. For comparison with a short-term limit that is either input based (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. AIRS ID: 123/9575/999 Page 17 of 20 EOG Resources, Inc. Permit No, 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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 PMI0 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 5O2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State -Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non -selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. AIRS ID: 123/9575/999 Page 18 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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 July 1, 2010 2.0 1.0 4.0 2.0 1.0 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 NSPSJJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § LB (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 J.J.J.J. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 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 AIRS ID: 123/9575/999 Page 19 of 20 EOG Resources, Inc. Permit No. 11WE3684 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 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: 123/9575/999 Page 20 of 20 Construction Permit Application Preliminary Analysis Summary Section 1 — Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE3684 Source Location: NWNE S16, T11N, R63W, Weld County (Attainment) Equipment Description: Point 001: (6) 400 BBL above ground atmospheric crude oil storage tanks Point 002: (1) 400 BBL above ground atmospheric produced water storage tank. Point 003: (1) 400 BBL above ground atmospheric emergency storage tank for vented gas. Point 004: Plant flare with a minimum combustion efficiency of 95%. Point 005: 4SRB internal combustion engine Point 006: Crude oil truck loadout Point 007: Fugitive emissions AIRS ID: 123-9575 Date: 7/30/12 Review Engineer: Stuart Siffring 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 shall be granted "Final Approval' 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? New APEN for fugitives arrived 2/14/2012 On what date was this application complete? 2/14/2012 I Section 4 — Source Description AIRS Point Equipment Description 001 Six (6) above ground 400 bbl atmospheric crude oil storage tanks. Emissions from these tanks are controlled by a Cimarron smokeless combustor (vapor recovery unit) with 95% control efficiency. Page 1 002 One (1) above ground 400 bbl atmospheric produced water storage tank. Emissions from this tank are controlled by a combustor (VRU) with a minimum destruction efficiency of 95%. 003 One (1) 400 BBL fixed roof storage tank used to store gas in the event that there is a need to vent the gas rather than put it into the pipeline. Emissions from this tank are not controlled. 004 Separator controlled by a 40' flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 005 One (1) International, Model NG466TA, Serial Number 674774-85, natural gas -fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 134 horsepower at 1800 RPM. This engine shall be equipped with a non -selective catalytic reduction (NSCR) system and air -fuel ratio control. This emission unit is used for primary power until electricity can be run to the location. 006 Truck loadout of crude oil. 007 Fugitive emission leaks from connectors, valves, flanges and other equipment. Is this a portable source? Yes X No Is this location in a non -attainment area for any criteria pollutant? Yes X No If "yes", for what pollutant? PM10 CO Ozone Is this location in an attainment maintenance area for any criteria pollutant? Yes X No If "yes", for what pollutant? (Note: These pollutants are subject to minor source RACT per Regulation 3,.Part B, Section III.D.2) PM10 CO Ozone Is this source located in the 8 -hour ozone non - attainment region? (Note: If "yes" the provisions of Regulation 7, Sections XII and XVII.C may apply) Yes X No Point 002: Is this source claiming exempt status for this source based on the fraction of oil in the stored water (less than 1% by volume crude oil on an average annual basis)? (Section 3 on APEN) Yes X No Point 002: Are these produced water tanks located at a commercial facility that accepts oil production wastewater for processing? (Section 3 on APEN) Yes X No Point 002: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 Rule? (Section 3 on APEN) If so, submit Form APCD-105 Yes X No Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 001 Site -specific using E&P Tanks 002 CDPHE Emission Factors (PS Memo 09-02) 003 Site -specific using VOC weight fraction 004 Site -specific using VOC weightfraction 005 Manufacturer emission factors for NOx, VOC and CO AP -42 for HAPS 006 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] Page 2 T = temperature of bulk liquid loaded [deg. R] 007 EPA protocol for leak estimates: 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 65,700 BBL per year (54,750 x 1.2) 002 36,500 BBL per year 003 721,875 scf/yr => 0.722 MMSCF/yr 004 36.5 MMscf/yr 005 7.8 MMscf/yr 006 91,250 BBL per year crude oil loaded 007 2.4 tons per year VOC from fugitive leaks Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 54,750 BBL per year 2011 002 36,500 BBL per year 003 721,875 scf/yr => 0.722 MMSCF/yr 004 36.5 MMscf/yr 005 7.8 MMscf/yr 006 91,250 BBL per year crude oil loaded 007 2.4 tons per year VOC from fugitive leaks Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 54,750 BBL per year 001 36,500 BBL per year 002 721,875 scf/yr => 0.722 MMSCF/yr 003 004 36.5 MMscf/yr 005 7.8 MMscf/yr 006 91,250 BBL per year crude oil loaded 007 2.4 tons per year VOC from fugitive leaks Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron smokeless combustor (VCU) 95 002 01 Cimarron smokeless combustor (VCU) 95 004 01 Tornado 40' flare stack 95 005 01 NSCR and AFRC NOx: 89%; CO: 87%; VOC i & HAPs: 57% Page 3 Section 6 — Emission Summary (tons oer year) Point NO,VOC CO SOx PM10 Single HAP Total HAP PTE: 001 0.02 3.6 0.09 -- "' 0.1 (n -hexane) 0.2 002 --- 4.7 --- — -- 0.4 (n -hexane) 0.6 003 --- 12.1 --- -- '— 0.3 (n -hexane) 0.5 004 1.9 613.8 10.5 -- -- 8.4 (n -hexane) 11.0 005 12.2 2.1 20.5 -- --- 0.2 (formaldehyde) 0.2 006 --- 4.7 --- -- --- 0.2 (n -hexane) 0.4 007 --- 2.4 --- -- -- 0.1 (n -hexane) 0.2 Uncontrolled point source emission rate: 001 0.02 3.6 0.09 --- - 0.1 (n -hexane) 0.2 002 --- 4.7 --- —_ _" 0.4 (n -hexane) 0.6 003 -- 12.1 —_ —_ _— 0.3 (n -hexane) 0.5 004 1.9 613.8 10.5 -- "' 8.4 (n -hexane) 11.0 005 12.2 2.1 20.5 ----- 0'2 ' yde) (formaldeh 0.2 006 -- 4.7 --- --- -- 0.2 (n -hexane) 0.4 007 --- 2.4 --- --- --- 0.1 (n -hexane) 0.2 TOTAL (TPY) 14.1 642.7 31.0 -- --- 9.4 (n -hexane) 13.3 Controlled point source emission rate: 001 0.02 0.18 0.09 --- --- 0.01 (n -hexane) 0.01 002 0.2 _"" 0.01 (n -hexane) 0.02 003 --- 12.1 --- --- --- 0.3 (n -hexane) 0.5 004 1.9 30.7 10.5 --- "' 0.5 (n -hexane) 0.6 005 1.3 0.9 2.6 --- ___ 0.06 (formaldehyde) 0.1 006 --- 4.7 -- -- --- 0.2 (n -hexane) 0.4 007 --- 2.4 --- --- -- 0.1 (n -hexane) 0.2 INSIGNIFICANTS (TPY) 0.5 1.5 0.6 --- __0.17 (n- hexane) 0.17 TOTAL PERMITTED (TPY) 3.5 50.4 13.4 --- --- 0.9 (n -hexane) 1.6 Section 7 — Non -Criteria / Hazardous Air Pollutants Pollutant CAS # BIN Uncontrolled Emission Rate (Iblyr) Are the emissions reportable? Controlled Emission Ibl r Rate ( y ) Point 001 Benzene 71432 A 46 No 2 Toluene 108883 C 42 No 2 Ethylbenzene 100414 C 0 No 0 Page 4 Xylenes 1130207 C 16 No 1 n -Hexane 110543 C 312 No 16 2,2,4-Trimethylpentane 540841 C 26 No 1 Point 002 Benzene 71432 A 256 Yes 13 n -Hexane 110543 C 803 No 40 Point 003 Benzene 71432 A 54 Yes 54 Toluene 108883 C 41 No 41 Ethylbenzene 100414 C 7 No 7 Xylenes 1130207 C 17 No 17 n -Hexane 110543 C 332 No 332 Point 004 Benzene 71432 A 2738 Yes 137 Toluene 108883 C 2067 Yes 103 Ethylbenzene 100414 C 348 No 17 Xylenes 1130207 C 859 No 43 n -Hexane 110543 C 16784 Yes 839 Point 005 Formaldehyde 50000 A 248 Yes 106 Acetaldehyde 75070 A 34 No 14 Acrolein 107028 A 32 No 14 Benzene 71432 A 37 No 16 Point 006 Benzene 71432 A 63 No 63 Toluene 108883 C 208 No 208 Ethylbenzene 100414 C 15 No 15 2,2,4-Trimethylpentane 540841 C 80 No 80 Xylenes 1130207 C 277 No , 277 n -Hexane 110543 C 379 No 379 Point 007 Benzene 71432 A 8 No 8 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 11.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. Page 5 Section 8 —Testing Requirements Will testing be required to show compliance with any emission rate or regulatory standard? X Yes No If "yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001 01 VOC CDPHE PS Memo 05-01 Site -specific sampling 003 01 VOC, HAPS State only requirement Site -specific gas analysis 004 01 VOC, HAPS State only requirement Site -specific gas analysis 005 01 NOX, CO, Regulation No. 3, Part B., Section III.G.3 Stack test Section 9 — Source Classification Is this a new previously un-permitted source? 001 002 003 004 006 006 007 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 Major What is this facility classification? True Minor X Synthetic Minor Major Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? Yes No If "yes" what kind of modification? Minor Synthetic Minor Major Section 10 — Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If "yes", for which pollutants? Why? VOC 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 No For Reg. 3, Part B, IILC.1.d (synthetic minor emission limits)? X Yes No - Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? If "yes", for which pollutants? Why? NOx emissions are less than 40 TPY. Yes X No AIRS Point Section 12 — Regulatory Review Regulation 1 - Particulate. Smoke. Carbon Monoxide and Sulfur Dioxide Page 6 001-007 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, 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 001-007 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 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/a-APENs, ConstruotiortPermits, Operating Peniilfs,PSD 001-007 Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 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 from production exceed 2 tons per year VOC) 006 Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8 -hour ozone attainment area, therefore, not subject to RACT. However, operator is using 0.6 (submerged, dedicated normal service) for its saturation factor. 001-007 Part B — Construction Permit Exemptions Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 5.0 TPY threshold (Reg. 3, Part B, Section Il.D.3.a) ' Reg I�tion:6 - New S.o� r elf�erformancerStandardsr;":' 001-004, 006, 007 None 005 NSPS JJJJ: Rich burn engines greater than 25 HP are subject to NSPS JJJJ when their manufacturer date is on or after July 1, 2008. The operator provided a manufacturer date of 2006, which is prior to the threshold date. Therefore, this engine is not subject to NSPS JJJJ. Regulation 7 — Volatile Organic Compounds 001-004, 006, 007 XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is not located in the 8 -hr ozone control area; therefore, this facility is not subject to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... This facility is an oil and gas operation that does not operate any equipment subject to Section XVII of this regulation. 005 This engine is subject to Regulation 7, Section XVII.E because it was relocated into the State of Colorado on 7/10/2009, which is after January 1, 2008. Regulation BniHazardous Air .Pollutants'=z;= 001-004, 006, 007 None 005 MACT ZZZZ: Engines subject to area source MACT ZZZZ are engines with a commencement of construction date on or after June 12, 2006. The operator provided a construction commencement date of 12/2006, which is after to the threshold date, therefore, considered an affected engine and is subject to area source MACT ZZZZ requirements. Page 7 Section 13 - Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (%) 001 01 3.14 lb/100Q gal VOC No E&P Tanks 95 0.068 lb/MMBtu NOx No AP -42, Table 13.5-1 NA 0.37 lb/MMBtu CO No AP -42, Table 13.5-1 NA 0.0204 lb/1000 gal Benzene No E&P Tanks 95 Crude oil Storage Tanks 0.0180 lb/1000 gal Toluene No E&P Tanks 95 0.0005 lb/1000 gal Ethylbenzene No E&P Tanks 95 0.0068 lb/1000 gal Xylenes No E&P Tanks 95 0.1370 lb/1000 gal n -hexane No E&P Tanks 95 0.0112 lb/1000 gal 2,2,4-TMP No E&P Tanks 95 SCC 40400312 — Fixed Roof Tank, Oil field storage of crude, breathing losses 002 01 6.2381 lb/1000 gal throughput VOC No CDPHE PS Memo 09-02 95 Produced Water Storage Tanks 0.1667 lb/1000 gal throughput Benzene No CDPHE PS Memo 09-02 95 0.5238 lb/1000 gal throughput n -Hexane No CDPHE PS Memo 09-02 95 SCC 40400315 — Fixed Roof Tank, Produced Water, working+breathing+flashing losses 003 01 33612 lb/MMscf VOC No Engineering Calculation 0 74.8 lb/MMscf Benzene No Engineering Calculation 0 56.4 lb/MMscf Toluene No , Engineering Calculation 0 Gas Storage Tank 9.5 Ib/MMscf Ethlybenzene No Engineering Calculation 0 23.4 lb/MMscf Xylenes y No Engineering Calculation 0 459.3 lb/MMscf n -hexane No Engineering Calculation 0 SCC 40400152 -Vapor collection losses 004 01 33612 lb/MMscf VOC No Engineering Calculation 95 0.068 lb/MMBtu NOx No AP -42, Table 13.5-1 NA 0.37 lb/MMBtu CO No AP -42, Table 13.5-1 NA 74.8 Ib/MMscf Benzene No Engineering Calculation 95 Flare 56.4 Ib/MMscf Toluene No Engineering Calculation 95 9.5 lb/MMscf Ethlybenzene No Engineering Calculation 95 23.4 lb/MMscf Xylenes No Engineering Calculation 95 459.3 lb/MMscf n -hexane No Engineering Calculation 95 SCC 31000205 -Flares Page 8 005 01 1.64 g/hp-hr VOC No Manufacturer 57 9.38 g/hp-hr NOx No Manufacturer 89 15.861 g/hp- hr CO No Manufacturer 87 Reciprocating internal 28.97 lb/mmscf Formaldehyde No AP -42 57 combustion engine 3.94 lb/mmscf Acetaldehyde No AP -42 57 3.72 lb/mmscf Acrolein No AP -42 57 2.23 lb/mmscf Benzene No AP -42 57 SCC 20200253: 4 -cycle rich burn 006 01 0.104 lb/BBL VOC No AP -42 0 0.0007 Ib/BBL Benzene No AP -42 0 0.0023 lb/BBL Toluene No AP -42 0 Truck Crude oil Loadout 0.0002 lb/BBL Ethylbenzene No AP -42 0 0.0030 lb/BBL Xylenes No AP -42 0 0.0042 lb/BBL n -hexane No AP -42 0 SCC 4060132: Crude Oil: Submerged Loading (Normal Service) 007 01 4800 lb/yr VOC Yes AP -42 0 7.5 lb/yr Benzene Yes AP -42 0 Fugitive Emissions 12.2 lb/yr Toluene Yes AP -42 0 1.7 lb/yr Ethylbenzene Yes AP -42 0 4.5 lb/yr Xylenes Yes AP -42 0 252 lb/yr n -hexane Yes AP -42 0 SCC 31000220: All Equip. Leak Fugitives (Va ves, flanges, connections, seals, drains) Section 14 — Miscellaneous Application Notes Facility -wide Facility Review A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold) and is a synthetic minor source for VOC, PSD, n -hexane and total HAPS. Page 9 Air Pollutant Emission Notice (APEN) — and.— Application for Construction Permit "'• �`"""_ ,• OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY `a,. TO-ZT_-ZT-TTOZ-N2dY-TOO-SLS6-£ZT L -LI Current Status (Check all hat app y) Reason for APEN Submit al Check all that apply) . DECAIRS ID #': 123/Q$-51001 B ADEN update o L2 2011 • ►5 New or previously unreported battery • ■ Previously grandfathered battery' O 0 Synthetic Minor facility Modification to.existing sources- Registration for coverage under general permit no. GPAS": • , & cancellation request for. individual permit': '`••-. Sr,, • Located in the 8 -hr Ozone Control Area' ■ Registered under general permit no. GPOI • Permitted under individual permit I I it 3b84 0Application for or Modification of an individual permit -"' ❑ Administrative permit amendment' • Other x.. For individual permit applications, check if you wanta: . ❑ A copy of the preliminary analysis condud oy-{he D1vi ign ` O To review a draft of the permit prior to issuance Company Name': EOG Resources, Inc. OGCCOperator #: L'i---7 2? ( •11 ( l Mailing Address' °: 600 17'" Street, Suite 1000N 'Cis'l riaL iee e'.o., ;els c h City: • Denver state: • CO Zip: 80202. E:4c£a "max 'mot' Contact Name: Curtis Rice Phone: 303-262-9946 Fax: 303-262-9449 Tank Battery Name'': Critter Creek 3416H ' Number of tanks: 6 /C Location12 (QQ Sec. Twp. Range.): . NWNE SecX,T11N,R63W County: Weld ' Total tank capacity [bbl]: 2,400 (400 ea) Calendar year for which "Actual" data applies13: 2011 - Year(s) tank(s) were placed in service1s: 2011 Control Descriptions: Cimarron Smokeless Combustor (vapor combustion unit [VCU]) Control Efficiency": 95% Condensate Throughput17 [bbl/year] Requested'8: 54,750 • Maximum for PTE caiculation19: 65,700.. Actual":. 54,750 While Controls Operational' 54,750 Other equipment at facility': VCU, flare, heatertreater, 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 coverkgs. Therefore, an individual permit is being requested. Estimated emissions at throughputs listed above. ❑ Check if the Division is to calculate.emissions. Emission Factor • • Pollutant's [lb/bbl] VOC {tons/year] 0.1319 Use /V/A for requested . ► 4 Battery- PTE'"s 4.3 throughput /emission Check if site -specific Requested Uncontrolled" N/A values unless emission factors provided Emissions' B Controlled" N/A requesting an individual to calculate ActualEmissions20 Uncontrolled" 3.6. permit emissions". Controlled'-' 0.18 NOx [tons/year] N/A 0.02 0.02 0.02 CO [tons/year] N/A 0.09 . - 0.09 0.09 Benzene [lbs/year] 46.0 • 2.3 n -Hexane [lbs/year] 312.0 15.6 . Wens serviced by this tank or tank battery" API #: 05-123-33103-00 Name: Critter Creek 34-I6H ® Newly Reported Well API #: Name: i Newly Reported Well API #: Name: O Newly Reported Well API #: Name: • O Newly Reported Well API #: Name • Newly Reported Well. API #:' Name:. ■ Newly Reported Well API #: Name: O Newly Reported Well The signature below indicates th t I•have knowledge of the facts herein set forth and that the same are true, accurate, and complete to the best of my knowledge and belief. If s is a registratio a for Coverage under general permit GPOI, I further certify that this source is and will be operated in full compliance with ondition of cal permit GPOI , . /2' 7 `/� Signature of Le y Authorized Person (not a vendor or consultant) Date Curtis Rice Senior Environmental Specialist Type or Print Name of Person Signing Above Official Title Submit this form, along with $152.90 for each Colorado Department of Public Health and Environment • For information calf: filing of up to 5 tank battery APENS: Include Air Pollution Control Division, APCD-SS-BI rx :_ 7Z' (303) 692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South 1 °,,r -,3d ')1I) registration to: Denver, CO 80246-1530 FORM APCD-205 Page 1 of 2 ECG CC 34-16H FormAPCD-205-E&PCondensateTankAPEN.docx 264914. a' 0 57. 7' O 0 Co 7 C 'O 9 o' n C Co ca 0- a 'O O z Co 0 7 fco • ti O O n CD n y Nw N 0. 0. m w. o' w w 9 1 o. o w 7 ox m s' R. w ^ N g ro o 7 c- o ti o a oo _• o on Co j' i • '<CD Co co N h ®❑❑ 000 Co Co 0. Loa CU)v O Cr O y F.' w Co 7 0 P a Co Section 04 — Tank Battery Information' 0 0 0 0 W Wvw c 000 t� Wv�W .7 9 NN� cri w la o • ' Or 22 w o 2 O_ 0 0- a o. 0 0 0 P O °. w N O • w O 0. = a 8 o n w 0 w o n bp o w w 0 o Co 9 0 m a B O 2 y O m • < n w n ^ U 0 a ^O • y 7 O 121 0 0 0 0 2 O Co 0 Co a n s Co 0 Co 0 'L 0 a C Co a w 0 w w 0 a d O a n 0) a 0 at cc J a (0G Co CCo b N N O Section 03 — General Information N Co Ro 'y z 2 o '. P 00 Co 0 0 a 0 Co Co a 0 co '0 w C :ssaappy pets -g :loeluoJ oy ttOSlad n Co aagamN anogd 9666-Z9Z-E0E opuaolo3 `.tan=ci O. S 600 17`x' Street, Suite 1000N N m ro < n w o oz. N N ❑ ❑ Co .0 O Co co " Co n n a w 0 w ro o t-7 n co. rn z co g b p O 0O O0 v O Co . w o Co o= 9' 0 0 • =.. Co 2 O - rd n z5 t-5 r 0 o x riy P .1 n LT A or-,' c Con Co • z=-3 w P g c& 6, c C - O '9 C C?S o o NLI v' s P C �. '-+' • o 5- D = 0 T N :uotleao1 aoanos NW/NE Sec 16, TIIN, R63W n 0 P. co 0 Co 0 0 aul `saoanosag DO3 n a O • V] Co o ❑ El ;lumpy —10 uopaag uopumaolul anye Co ❑ ❑ .0 • A C C Co Co O • o d • z a ❑ -3'. O • c w • ,0 3 00 • 0 Co 0 Z N n m MT ' p rn n o y E -o c_- co ' cn A Section 02 — Requested Action (Check applicabl 00 _,.o Po Cr :GIluatudtnb3' !l! H C 0 S. co n '0 O a a tit O .➢ 0 Co Co o 0 a o &) Uc2. P) 0 C U) 3 C 0 1 E_ 8 N Co "4 v L0Z-QJ(1V FMUOtl wco N -I 6E4 FonnAPCD-?07-ProducedWaterTankAPEN doc a d a n a a 2 m y. S TF rn -0' F w '� _. P- H h 0 a rn c o- a Cr '� o a 22 LaTYo ny. a a = o _0. n a n rn. c E10.o y P ti ` n V ;H, w - a Q a or Pa a �P �aa3 PO' ?:0 a =co o a y a d - < w w a S. w� a P- a K ( a U =- aa O OO �, w C n w w 2 ;"- 0 N N E. 0 O w a a 2 0 5" o'64 ' H a C 0 ow rn a Sr. Environmental Specialist a F a n Z 0 n a 71. at a 0 0 w a a a a a 3 00 a 0 D a a a a R: w a' 0 x a 0 4.0 N a a a 0 CO a cc a O J 0 O a O N O co- -0 o. siseg paj(oiwopnn Et c Q c S a S a a w o tr a 0. O u a N 0 144 O a 'AH HHdU3 '3H HHdUJ aHrITIO O t a . 0 0. 0 o pc a a C, O a a O a a 0 a gag - 80 mums a a 0 a w' a 0 a C 0 0 0 a 0 a spna) passudAq st nil a a a a ? .0 a. a a < 0 n R3 a C) 0 0 n 0 a 0 0 a 0 0 O a m 0 0 y O 0 0 XI a a O 0 a v c a 0._ a0 cm n 43 Ro a 0 m C) a x_ a B C] O 'f a a a Di a 0, rn a a w x. a 0- o N < a a• O O 2 E x a rn ro 0 O- O O 0aO ? Col a N O. o a ` a ❑ o � .0 y 4 a CD a a a B O ny o a 0 A- J tb m 2 C) -e 04 aolsngwo3 ssala)lows C] z J CO U J b7 o x- y a 6 o .p y co 00 a o a Fr 0 N 5a n a' 0 a a a 0 a 0 C O a C CI, a O K _n 0 ❑ a ❑ rn x 0 R. a Co 1 LA CA Pg 2 o co N 0:0 H E 0 a W 0) C to N a' b Section 05 — Stack Information (Combustion stacks must be listed here) C ro 0 a 0 a V) F 0 a m M a O 0 O P 0 a a a B ither Lat/Long or UTM) :aaqurnN wand Emission Source AIRS ID: a 0 a O n O y -t n co at - a m -S R O a a n a a m tt OOZ-a3dY ]f HOJ b 0 N 123-9575-003-APEN-2011-12-12-01 o _ O 6 114'0 o w 9 mr 0- Co 0 0 a a G w N' o o 0 0 a a 0< 0 0 a a w w T a '0 e a a o' o 0 0 y c Co 27 d Co• 0 0 e/sn 000leys- q og- Co O a o iis5ed aducts: ry � Co Co 0 C o a co d5 w r+, R: N -4 -"ten Co 0 a co 0 Co R g a 'o 0 E Co rn o .. M Co .o n C O '0 JOH'°N lapojN 0 utssaaoad — uoiaaas uianlae_inuu ,AJ/ < ° Co F a co e. —a R N o rn ° o "y a w Co 092 Ez 0 a w,p 00 r .C 9 7 a w 0 0' - B Co o w a O 0 Co w U1 on .C O Co CD m Co z W L., N ° -4 oo2 ° a a Na -3 oAan4 b m d^C.0 O.nOG '9Lx p z O_ Co Co rJ R d w r0 0 o w G a- 5' et C. R. rn . o o' e 9 nn m0 a n w y a2 o aC 9°' w o.< ri o o '�F go '5�:a. -.- ° O Co y• OO O.R Co 0 o C 0 m 0� to C P S '0 O 0< 0. y co _ CO m a rTi Or, a Ey p y' Co O » Co o a .0 Co & s v20 iD z i.'.N a _. w G9 go- rn b a co UP m 2 -Ate- -' Z y o- LM 0 " a . 3 0 a 0 Co. a o �z-t 00 ° E P, ? 9 'o 0 o c P.)2 In 00 � o .00 ° O T o' E P Co w 0 a o_ 0 C H b' or w 0 A O^ o o 0 P d a Corcrqo Co cp a X 0 Co N Co 6 F 0. Co C O 0 0 y $ a --I Do c co co Co S Co w 0 Co Co o. 0 loo Co m 0 0 0 a 0 0 S Co 0 N 0 0 ro w Co a P� 0 0 Oro nn o — o c 0 0 0 E. H o o w w o. n 0. C m p o y 9 Co c m 3 C y O Co 0 w 0 C Co Co a 0 zno o CO o m EIE, A a A O C C C n n c Cr) Co n s- 0 Co 0 " c n n C w H 'Q — a 0 5 Do 0 y 'C o .Cj — Co rn H CL 5,..^ O w y O a O a a y m' p Co tr] o o=8 c O Z Co 0 Zr a z Er a . Co w a o w _ .ri O L ^ _a r o ≤. n 0 rt 0 y' S O 2. D. k Co a g FE 5. a a0 �0, 0 21:58 0 Co w - o o < 0 rn w Co m $ o S CDCo 0 `0' °.Cl U 3 ° m � ' 'a a'ot �o no, O 9 0:. �G § m C_S 3 O y 'J' Na rt 'Dv 0 0 . v ti., �.'0• 0 Co .0 0 FS" o' —to- co o.Frlr 0 aco C' Co 0 0 on Co Co c. Co z N n 0 0 n 0 0 C y o Co o O L< °: w w o. P. 3 9 NW/NE, Sec 16, T11N, 1263W 1I91 -PE laolD 10;41-O .aul `saaanosau OOa Nz a O 00 o. cn o ❑ ❑ ❑ ❑ Co,Co -2 a 'E o 0 CO r.a ra- g a C oO a a '< T Co O 0. a Section 01— Administrat uoyluw.lolul a all — ZO uoilaag uested Action (check applicable request boxes) rni CO 0 Equipment ID to identify ho' 2 rs- r F 0 0 eady assigned a permit #i & AIRS ID) (uiauaD — 11111 -IN[ uorpn N 9- w aani stlanj S (uluautuoalAu,3 •.ts 0- 0 0 e C g 2 Please use the APCD Non -Criteria Re , ortable Air Pollutant Addendum form to report pollutants not listed above. N la no VOC wt fraction n P 0 0.00 C. N :`CD 3 o 0 6 to 8 o n O C) H3 no 00 0 o y o g -4O 0. o re. H -C• 0-:o w 0 %tn VJ N5O C-0 0 w n a a m ,� 0 0 n a 0 7 to fE: w 0 w .3 c _ a T' • o' w h e w 0 w w 3 S y C 3' Y T 0 0 Co w a PA w T o De n o n, az r a c 0 Section 07 -Emissions Inventory Information & Emission Control Information 'Requested values will become permit limitations. Requested level should consider process growth over the next five yea a' aLL P Ww. C to n n PD 9:. Ul PC- G: C of 44 9+ Ci CD: z p m n. :oN not;ros!;uapl ;uausdtnba luedtno0 0 T CD U CD z 0 Section 06 — Combustion E uonnmaojul uo!I x O rn oa co a N 0 ent 0 C Di- 0 PD y d a N 0 N II 0 4 P ❑ Vertical with obstnteting raincap ❑ O o co 3 d • o • 7 (sagau@ gip!M :(aquosoQ) aaq;O ❑ at a co 0 r0C < < S ;? 0. C) a °'pp H a aEi -'E w e N'C 0 0'H 0 a La a A 01 w 0 CO 0 Section 05 — Emission Release Info G O1 -Di G w rn a co a▪ . N w w 0 P a C N y O - O' F o C a 0 w O N d 8: tg 8 0 d %.D 0 0' AIR POLLUTANT EMISSION NOTICE Permit Number: C4..' O VI) K n 0 PD *Cr Cr, K 9 ry CD a P≥ 00Z-COkIV WHOA Z-NadY-b00-SLS6-£ZT ulssaaoxd — y0 ubilaeg mim3EJnnnjAy ment Information & Material Use F - a as a a rn o a O aza a `°' e yz p N w w a -.1 a 1< a a 0 0 S _ 0 a ti a ao ro a a 5' O E.', N O EP - a w ti o 0 DO 0 For new or reconstructed sources ie projected startup date i Section 03 — General Information 0 z.. a 5 w :ssaiPPV a tis rice@eogresources.com 6666-Z9Z-E0E Person To Contact: Curtis Rice opzao10D.aanunO ssonspv 9ulpeyy 600 17t1i Street, Suite 100 b a CD 0 cn 0 'G0 a o = T .Z Y O II O O' O'5 5 3 ag. o a Le to a z z 5;c o' a a R. a - rn R SLZ`S ntogenal3 ME98 Ni II `9I aaS `UN/MN I{9I`6E rlaauJ aalllao aul 'saaiuosag Dog opz n -a O o00 a. P. o w a a— ❑ ❑ ❑ ❑ ❑ ❑ r „ ED .0 .a a a m a up p C a a. n n o a N. .d � 5 v w z 3 0� w y' 1 a 3 t y'w a y o a. ° ° yo y a O < .O n n ? a S Z 0 O a a a a n a = ❑ ❑ 06.E a a T a c a Ea. -' Or a .°.". k y Q a H n a y o a .:I. ' a+ .n • a a p O z Oa9 a a 5 0 "ttap 300 Fr ,�, ,r_ y w • z o o' a o it 00 51 tri o' a p a. n H O z 0 Y. a. Gal a 3 .00 a a a n S a•o k P O � `< D S ▪ r� a Request PORTABLE source permit a Dn R z 9 S 0 a e at O R o. a o' Mu -WV — TO uollaaS uollewaolul anpua all — Z0 uollaaS a a a T a a a az rzt `O 0 R a rn o' E. O 0 a a a A C a H" a a a n O n y a Emission Source AIRS ID: 0 N aoP'Nddtlleiaaap-00L-C3dtl tuorl aseld H91 -17f 3J 0 .00 d co B 0 0 M co CYO `G 0 a oc gam span] V) m • ro C, R Co O CD P. S CO Co N p a o" 0 5 T C G S oraD Dor 5 o n Do �. Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. o VOC ro -1, a O o 5 Co o o. 0 o � - o' Overall Collection 'Efficiency e Control Efficiency (% Reduction).. 0.37 O O Cr o • n 00 W " D J Co 0- . 0 a C � o w F 'AI in 0 n Uncontrolled (Tons/Year) Actual Calendar Year Emissions' Controlled (Tons/Year) o o.: o o o 0! �� ViaFr Requested Permitted Emissions4 30.7 O ,O O Controlled Tons/Year) •iii AP42 Tbl 13.5-1 VOC wt fraction Ill 0.002 gr/scf AP42 Tbl 13.5-I Estimation Method or Emission Factor Source Section 07 — Emissions Inventory Information is Emission Control_ Information a x a9/n1EllAI J W9 a,COasINW S'9£ 0' (AHH) Jas/mf 6pS`I a: co w z O o Cm N 0 p Company equipment Identification No.: Ia1nl°2JnuEIN Section 06 — Combustion E C Co T C 0 O Co c B uopeumululimp x O 5 c 0 o. CD oc 0 RO rn n T to O n c ry 7 ❑ C7 w } Cti N II auo }pap) la O' deomem Simon, LI Horizontal ❑ Down ❑ Other: Length (inches) — (sagau!) glp!M (aquosou) rag40 ra o PT p ibe u A v0. R < C 5- 9 5- 4 5 2- e co CD 0 0 off C 'a' CP w CD 0. 2.. ) 0) O . w co d CD C) CD 3 CD N C'i Z Cu CD c).+, CD 0 CD v C 0 CD 0 ' 0 U) C ❑ CD CS) CD CU Cn CD .C C rh CD O T J CD 0 r- 5 0 N co 0 C m nD GsiN si1Jfl3 CJ) CD m C CD 0 U CD cn ✓ CD Ca C 0 N CD 0. O 0) O 'C3 Cy CD CO CD Q3 O m O 1 m CD Cl) CD C) C. C. ueoS 6uipode{ N.) -) CD • CD CD J [7 J D o c v 0 m co 108883 540841 71432 Chemical Abstract Service (CAS Number Toluene . n -Hexane. Benzene Chemical Name • OOD xl m °7a s c4 95 % 95% CO Cr, \. o. Control Equipment / Reduction (%) Wt. Fraction Wt. Fraction Wt. Fraction Emission Factor (Include Units) Gas Analysis Gas Analysis Gas Analysis Emission Uncontrolled Actual Controlled Actual Factor Source Emissions (lbs/year) Emissions (lbs/year) 2,067.2 16,783.8 — 2,737.8 co C+.) CO k a W :P W it:) L rn 3 Cv 0 CD Cn 0 C) C N . C) r/C CD -0 co m N O C) CD Cn n 0 3 :;oeluo3 o uosied C) C CD •'O 71 0 X .'CD Z Z CD CD ri CO -.4 0 N C) 41. c0 CO CO . [ 0 NCa rn -O O "0 Es• 0 CD. 3 • .] r a) 7-7 O .: :C `5Y o cp. Z Z m CD C) Cn Z a) L) n 0 C CD' a N .O n 0 C1 CD C7o 0 0 N 1n O CD CD , 0 C (7 CD Cn C C) rt C C7 CD :JegwnN ai Said. 0 c> 0 m C CD EDT O' co m ltd co . 'CD 7:1 O CO C. O C2 U co C) c m z co g _� O 3 0 m C TOZ-GJdtl W1103 a) Cc 410. Ha. 123-9575-005-APEN-2011-12-12-01 N ❑❑ n n n- or 0 O 0 x x O 0 .0 • A y y a o O 0 O 0 0. 0. w 'w Pt b O CD O O 0 0 b cc 0- w C C) m a 0 O O b O a n oO. 3 5 v w 7 ro CiF ' x w ❑ o0 ap c 0 'p a- n w W It Z ro Z ❑ Zr w_ p� CD ❑® 7.3 CD ono 0- cp 0 leuopeuaalui a Oa CD 6 CO O 6,44 m' a o a Section 04 - Engine Information £ a a' • o O O C • O O o not C y' w a w m a • D- a. C 0 VC 0 o w w O rn O O O 00 O e j :stains uoileailddy a 0 2 nq :suuo; Wady Na .' •0 DO = o n el o 0 b7 C 0. _ 0-�a S 0Pi; o.0 a _ _ y 0'o' n n0 W do o 2, �° y y= rn Z a E. G N p 7 N n~ w w (D < 0 a d a� - o if cD o. 0' m a m y o n '' C _ .9'b m k m m o O -ti M s 0 ,.c<D 0 0 0 b0 ▪ c ,.5_,., a -c-3 a o 2 o.. N = O '.nT `g '.O 0 '^ °▪ D 0 a' n a 9 rn = .p N ti f v O . O. ^< O y n On 0 'ad rte- Cw w cn < ' Ni ❑ v • z mN Cpp.3 P- 0 0 0 0 0. w� = S < 0 o 3 R 0 0 'o CD y a 7 O O Q pS g. ri PO W W W 3�r 'C CD n . 0.. o d =-J QY n3J "f bcD 0- R ? G-' o N N 11'ak&. •' �-9 cD ° "aC 0 W 6.4 -Pa. -c --PP. O (T : o °0° 3 T thD0D : 1\3,�vyro o °0 -'-0 OaanH Oy mny row o'er-� -J N c n • 0" a C)= m N 6 C O tra 0 S 0 u• O N Et c• c, C m O y n n ▪ 0 n H 1 w 0 n P 0 tif w grz C m n F a. a N O O N m N O a >iaam/sAep N O For new or reconstructed sources, the projected startu a 0 uopemao;ulleaa 61t6-Z9Z-£0£ opeaoloT `annum :ssatppy 8agte}g 600 17`h Street, Suite 100 ro 0 xn 0 g O O 05 o p CC Z0Z08 :apoa d1Z SLZ`S :uouenala. :uoTlaao] aoanog ME91.I `Nff.L '91 aaS `IN/MN 0 e a 1191-7£ 8aasO aa;lup •aul 'saaanoso)J DOg Section 01— Administrative Information cn p mod DUD m ❑ nn .❑❑® ep O G o = C C N CO. 0 C." A y �' n n y n y OS permanent replacement O. co o. Ni 0a CD z C o. Yg roa '-,. "0 a "Pi z r n n z ° —' tal c, 5 ft'3 ° F C a< a: 3 Z C o O 'nj~ a (l w 00 co 0 O n £ A 0 K f n. y w ❑ ❑ �O n = .. 9 "5 ea 0, 5 C it; o .p (5' x o '--pi n n 0 n a o o �' m 9 a w y n n a- -, o n O :. E [D O £ a o 0 0 �. ti n '0 co3 ^ Eb F o...a. N v a a' "".' 0 -Cio op Q 3 I o,y'y. n p CDi G m 'CS "'\ 3 OJ h C'y O rn .� (, r M1 4, • ri r=1Fla < a' 0 rt 'C F O w CP n . - C. -to -1 .: '°— CD O co a - y CD 6 e ug g jm aoreaaua3 s I1�1. H E lT tmi W y Q' ri Goa O Z z n 3 hj b CD rt O O O CD h _M C ❑y CD CC '4 CD [Leave blank unless APCD has already assigned a permit # & AIRS ID] O. CD Pia er- CD Internal. Combustion En co 0 N• O•� CD n'" m.. . 'r C9- fCD . 4': f1: •o • b d b Mc, N O • M N • _ •W V— 80 uoyaag in 9 Cz3 o CD 0 5 ' B O K d'p'i co CD F-',' o Fir 9 a 0. P. Formaldehyde I 0 O VOC XON 1 un 0 r. '0 ?� 7'5 K o .._ CA 'a ..•C_ • . NSCR j NSCR NSCR • AFRC I 0%7 I 1.58e-3 1lb/MMBtu I Please use the APCD Non -Criteria Reportable Mr Pollutant Addendum form to report pollutants not HS to based on actual emissions refinrted herr. ff LEt s.ie..0 a......et �...h . ,... F e�.,.al L.. L---1 _— _______._� _ :_e__e_ _ nnn ` AFRC n'� :m,..s: IA e LSI e Lit o`, .00 o IA e 0 o ,rya el:: �: o. .O,vyp.''4 ( a 2.63e-3 2.79e-3 O W G Ls N a ., " q' $ a CV1:6 C C E '5 eti=Cols C c` a o' G C . '4 .E 0.010 0.005 AP42 Tbl 3-2-3. ted above. 0 01 0 rl 0 A • ,0:: I= • •.= Q ,. 000 b a GO 0 O 00 o Os N .2.6 c 1p " iy ua•:; » _ a, - 1 a AP42 Tbl AP42 Tbl 3-2-3 II AP42.Tbi 3-2-3 II Manufacturer Data II I Manufacturer Data II Manufacturer Data J.f C ,N:1-. C]. uopeuiaojuj. lo.[luoD uoisspuH ip uoieul.lojuj A.to}uanuJ suoissitua — LO uopaag Is.this engine equippedwith an Air/Fuel ratio controller? z O 'ill/33s Z68 a,,/1osIAIN tl L (Awl)Ps/')B £Th`I • .01 µGo - iup, v.yy.9 : P o•. it O A 01 A w A O e Co a a „ O v. 4 P• . d O 0 0 C) 'C3 8 • C n. . CC • m ((9� CD m p 04 0 K C • O a och I Pi ♦•4 ti co O � n . CI ed o f9' to l9 L J co w' Ua on .r -t .y O CC z . Fl CD o . I 0 r) . co CD V CD co a o K a A C C m C �A f7 CD 0 • O ro CD CD n C) a 0 0 -n Ul a> 3 a a a nt o l�' �� o 9 ^ w d y 8 b � J c n • -a w z m 3 0 p G ❑ . o.a o n o- < R a a ry o.- ..2. 2. w 0 y Hrn � j. = r — 'O' m 3 w. ❑ y PD m 0 OP N T0-ZT-Z•C-TT0Z-NadY-900-S LS6-£ZT m O 0 O Ca c •Qwlq xapu!/SOgozaclutiargo/uA/^ 9 qp ro o z 5 o' a. w 0 w Lel D a a y P 0 0 a G 0 0 X m a w 00"- 0 0 0 0 u aO!L0 C0 Q0 Np 'DI .a v 'ED tn O 0 a EL O ' < 0 0 C O Oo y a o, b r 6 Crude Oil and Produced Water IJJ a w A ooP24.x oo n o _ 0n E- S m o - O O. p nw m C o © 0 0 on 0 E. .-Ea„ 3 0 0 ^ °a _ w S " F '= o g0 w wca.a 0 w. - a o < 7pa P a t; m Z 3 3 0' w -+ 7+74 ® ® ® , m M 7 N -a y S p :^ '.' y y ..� O. M O I EZ a c ob o. o .p " ": y -I o. "' 2 wo 0 m.sN N 3 g2 2 N m o• ° a m o. _ c c G. o o. y 0. n 3 rn m N— o 0 3 'y O o O w - O n 1( 0❑ w E4 E 0. w ti 2 0 n 0 0- o w a w a O :p 2 oo ac p p w Er o. - w rt y: m d y X000 z 0'›- ry O co Li. c < 0 • Zrn co w at qua a ° 8a a8. a c„ 3 o a 0 Ma m n a p o 0 a y o rp p _xDEEP _ a 9 Ew w O 'p `< £ y y 0 p a. a 2 a a rn p ^ Ofr -< n .n. a 9 xona m ^ a rap 2 y w N 7 0 0 w J 0 o rn o c w 0 ❑❑❑ ❑ E 0 0 a 0 0 NEMNO 0 0 0 0 0 DOD ID 0 0 O 00 0 3 a o mou) 1,UOQ cozy o °P. . M _ r 0- o cab 9 'Fa 3 O' O m a a m 2 0 0 0 ta 0 w o. O 3 co a 0 0 w 6 .5 DO to re O w a a N N O a w a PD o. OD S n 0 e n 0 ro 0. w 0 "C' 0 Section 03 — General Information 20. N o moa'saaanosaagoa'rviaaia spans :laeluoO oy uosaad :aagmt1 auogd 9P66-Z9Z-£0f opeaoloD `aannaG IN a 600 17th Street, Suite 1000N CID O NA N tit -a U ❑ ❑ a L ❑ c a v 0 0 a y w 0 0 0 a _ th y.Dab x y " c, d ro o' n y y . a m C Z ' 0' 0 w a a T SJ 0 0 n L< m r K :o uuad of amp lot' !ma a0; suotssfwa a o a w c a m` 3 o9 O ycriatf c ro h t3 NW/NE, Sec 16, TI1N, R63W a Change process or equipment w 0 0 ❑ . w H9I-6£ NaaaO as;liar �z o co W aa c 0 a 4 o z n � a O z a 0 a a ti c e Section 01 — Administrative Information ?2[ — ZO uopaa5 p CD tit a 0 0 n a F `0 -0 or - 0 '0 m ?F: ro w m o m z 90 o do � ;nopzo7 )lanay CSE z 8 Z yo p F O _ PL,' = j L' -a y o roi o Z 0 ci Es R. o z o H '° t 3. p n d _ ry rF O• = i o a R. 0 K 2 0 y 0 n o O attj c8 5 ❑ a m n 0 8 K' 0 5 cnE I g K w n o 9 E:3 a r O ❑ a ❑ N CD CD 00 0 En 0 N d. PD pcd n P N 0 0 _ n co 33. co 0 a n z 0 earx Span'3 En .<0 a a CD En a w N CD n n 0 0 n CD m C 0 O CD 'U E T 0. a o. c 3 O -c 0 0 m m 0 n o. 0' _ w Co a m rn 0 co En CD a 0 0 n z 0 N e 0 0 J 0 0\ W a G a 0 0 0 d E o o o 0 1.11 N e 0 00 0 co 0 O O 0 b a O a 00lt(%1^+)(xdl) F 0 0 F O 0 0 0 10 co 0 p w a DO a 00 Emission Factor Documentation attached L Section 08 — Emissions Inventory In rmation Sr Emission Control Info' y > a m = = < a = [' a- n a a < = O a o' o [ z o o `0 502. w L 0 am rn It) ' h n o a' O L< O C rp 0. < 0 0 C C tJo lo -'moo lot pa CP Ov 0 00 O m1em iau.mq mild CD s -1 CD S w 0 O 0 a 6 R c 0 o 0 _ ≤ o a En a a o 0 O 0 !P. 3- w -- O a C CO y o Manufacturer Guaranteed: 03 — LO F0'}30 xo;uI aornoQ 104 wEor 0 a °= 0 0 7 23-- 2_, II 3. 00 w N 0 O..{ "a 4 A w a u a N En 0 Cn 12. Lit -=n CD "5" 0 co Eir to "co N 0. a En n O O a m K 0 0 7 0 3 c o' a. 0 0 w d 3 C 3:3 0 0 agwnN altnind .LfY lOd HIV v Vl e y 0 2 z ® o n z Rov z o ro so ry En o.� on ow y H- C - - o = 0. C cn C o o' 6 c • n T co CTO En a M Fi £0Z-QOdY IARIO,I 0 Co. w 0 N w w .0 0 Co 0 d w S y ' A Q W s h a ro m 0 to 0 Co 5 O G o. G ❑ ❑ CP o 0 0- -0- X % N o aco w a I a- H C 'O .n Co 0 0 oC 0 o 'o rs t< 6 I 0 0 o '^ ' O 06 o. Co Co Co Co Co It I 1 9 N 7. O co O I-' 0 0 a o7 e n N O I G o a o a 0 0 o T' 0 R1 0 `a. A w_. O .0 N W U O: 0 N 0 J 0 e w O 0 N O 0 u, O w b 0 e O o o r ©Co N v O Oi O O O a O O O z O e e g' N w O 0 w Section 05 — Stream Constituents List any other NSPS or NES P Subpart that applies to this equipment: 40 CFR Part 63, Subpart HH? Is this equipment subject to NSP 0 CFR Part 60, Subpart KKK'? ag-60 uot1aeS uogemi01U1 -0 cto Y X90. 9 o .P m y e C p'o IS C] r aC E..o ? $ a d n/sn-oa'alels-a Co. o 0 T .. rn Co rn Oh Co aer Co. W W W 0 0 00 Co a rn rn o 0 0 e G N N N o wwL..) S 9 0- u w o 9 0 ° CLn,4 ^x H Co as f d y S N 'O' _ o m n^ en o' i= C' o Co C)`G Cd bz arnm' Co o ,ti, o_ o' a o. • i 0 r 3 w G .,, ro d o Pe,-� a y „a Co o c o O°nS F Co Co a`� 2. .O o w a3 v rd. a 0 o o a o g o ° c i23 LP,0 C Co "9C Sr S O ' G C a z hN Fa Cg 5t tri O ''J 0. 9 r e° -. A' a aye w 0 a v a Co ro a a Z B 3 Co ' 0 0 Co so d n C ≤ Co z M 0 Co Cow O. N. x g 5 0 o o 'M O y µ G b a a g Oig 0 G a r o 0. < F w o Co a CoO n , o � Co F n � S N -" o Co G 0 0 0 C R II m a g Section 03 — General Information A o a. 00 :]ae;uo3 01 U0SJud c z n :aagmnN avogd 9666-Z9Z-E0E °peiolo° 'notion o. 600 17th Street, Suite 1000N N h7 0 ` P GO N' N J ut Company Name: EOG Resources, Inc Source Name:. Critter Creels 34-161-I Source Location: NW/NE, Sec 16, T11N, R63W Co 0. DO Z Co Co o 0. < Y o Co Co °' w 'MI _ CrCl Co Co Vo"tri 9 4o v , 0 z _• I 0 m g. w 0 y o F h o -. tV 2 a w 'o y d : s‘,1 2 R - a -1 (� 0 co T .w Clg a ❑ ❑ 6/\ � O N CO o. w K w n l. 0 0. m 2, (� w 0 o r o ate c m w fl y 9 w w O O o T. 9 O F `" ro Co Co O a G 0 c S S 0 Co xa 04 NOLLVJIHIQOIQ 450 Request for NEW permit or new reported emission source Section 01 - Administrative Information au — Z0 nollaaS 0 0 Facility Equipment ID: - Fu Co [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.]• :iagmnu;imiaa f [Leave blank unless APED has already assigned a permit II & AIRS ID] Emission Source AIRS ID: orient Leak Emissions :CID o c .0y o' 7 � y CD K C : nC. CD 0 0 w o a 6' 2- 7 9 . O. 0 Emission Factor Documentation attached o;uanul suolssltug — Information & Emission Control Information 0 O. O O w m 0 C. C • C C- 0 A C CC 3' e, 8 181 ie n C c 0 0 0 0 04, LA on VI N A •'tCJI A ►�+ O• O..� 0 0 a . O 0 a CO 0 m Q O 9 67 O ❑ ❑ p0 d R. 'C r • 3 co ge 2,. p F4. •- o °O oo d so rn E'#1. w o n • e 45. b � g. N C �.n ❑ ❑ t7 CD z ti (13 • 0 ° t7 ca Section 06 — Location Information (Provide Datum and either Lat/Long or UTM) aZ :aaquxnH JEuuad. Hello