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Home My WebLink About20132373.tiffSTATE OF COLORADO John W. Hickenlooper, Governor Karin McGowan Interim Executive Director 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 810O 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 August 14, 2013 Dear Sir or Madam: Colorado Department of Public Health and Environment RECEIVED AUG I a 2013 WELD COUNTY COMMISSIONERS On August 17, 2013, the Air Pollution Control Division will publish a public notice for EOG Resources, Inc. — Holstein 11-28H, 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. Please send 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 rafe, CL -OL : ELII 00 2013-2373 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 REQUIREMENTS TO SELF-CER ent dda Public Health and Environment Air Pollution Control Division UTO-RIZATION 1. 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). 2. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 3. 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.) 4. 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 5. The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: 100 tons per year of any criteria pollutant AIRS ID: 123/9001/999 Page 2 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Public Health and Environment Air Pollution Control Division Emissions of air pollu an s sha no ezcee.`t'fie iollowing imitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type NO, VOC CO Crude Oil Tanks 001 - 0.5 - Point ET #4146 - 002 - 6.3 - Point Flare 003 4.8 76.7 26.1 Point Truck Loadout 004 - 10.4 - Point PW Tank #1 005 - 0.36 - Point Fugitive 006 - 2.4 - Fugitive See "Notes to Permit Holder #4" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the synthetic minor status of this facility shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate monthly emissions and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all emission units, requiring an APEN, at this facility. 7. Emissions Point 001: Emissions from this point shall be routed to an enclosed vapor combustion unit (VCU) that reduces uncontrolled emissions of VOC from the crude oil tanks to the emission levels listed in Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 8. Emissions Point 003: 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 Condition 6. Operating parameters of the control equipment are identified in the operation and maintenance plan. (Reference: Regulation No.3, Part B, Section III.E.) 9. Emissions Point 005: Emissions from this point shall be routed to an enclosed flare that reduces emissions of VOC to the emission levels listed in Condition 6. 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 006: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events AIRS ID: 123/9001/999 Page 3 of 14 EOG Resources, Inc. Permit No. 11W E1462 Issuance 1 Public Health and Environment Air Pollution Control Division used to calculate ac ua emissions` and t e dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 11. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit Crude Oil Tanks 001 Crude oil throughput 146,000 BBL/yr ET #4146 002 Natural gas vented to atmosphere via emergency tank 0.375 MMscf/yr Flare 003 Natural gas flaring 91.3 MMscf/yr Truck Loadout 004 Crude oil and produced water loading 200,750 BBL/yr PW Tank #1 005 Produced water throughput 54,750 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 each actual monthly process rate and keep a compliance record on site or at a local field office with site responsibility, for Division review. 12. Point 005: Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained for a consecutive period of three years. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 14. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.1. & 4.) 15. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.). 16. This source is subject to the odor requirements of Regulation No.2. (State only enforceable) AIRS ID: 123/9001/999 Page 4 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Public Health and Environment Air Pollution Control Division 17. Emissions point 00 - e loading o7 crude of an produced water into truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) OPERATING & MAINTENANCE REQUIREMENTS 18. Emissions points 001 and 003: 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.) 19. Emission point 005: a. VCU's shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed VCU, or by other convenient means approved by the Division, determine whether the VCU is operating properly. b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing and 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. AIRS ID: 123/9001/999 Page 5 of 14 EOG Resources, Inc. Permit No. 11 W E1462 Issuance 1 COMPLIANCE TESTING AND S PL" Public Health and Environment Air Pollution Control Division Initial Testing Requirements 20. Emissions 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. 21. Emissions points 002 and 003: 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: lb Uimser, a tbnwL ' 1 3cf — benzene wt. Jfracst43-e pint;a 'lb{Aix f. 22. Point 003: The owner or operator shall demonstrate compliance with Condition 15 using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section I I.A.5). 23. Point 006: 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. 24. Point 006: 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. AIRS ID: 123/9001/999 Page 6 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 ADDITIONAL REQUIREMENTS 25. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, I I.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 26. 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). Public Health and Environment Air Pollution Control Division GENERAL TERMS AND CONDITIONS 27. 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. 28. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 29. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once AIRS ID: 123/9001/999 Page 7 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Public Health and Environment Air Pollution Control Division self -certification of appoints has oeen reviewed an approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self -Certify for Final Authorization section of this permit. 30. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 31. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 32. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 33. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 34. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Laura Strohkirch Permit Engineer Air Pollution Control Division AIRS ID: 123/9001/999 Page 8 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Permit Histo Public Health and Environment Air Pollution Control Division Issuance Date Description Issuance 1 This Issuance Facility -wide permit for a new E&P facility issued to EOG Resources, Inc. This permit encompasses points 001-006. This facility is synthetic minor for Title V and PSD. AIRS ID: 123/9001/999 Page 9 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 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 anyambient 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 Il.E.1 of the Common Provisions Regulation. See: http://www.cdphe. state.co.us/req ulations/airregs/100102aacccom monprovisionsreci. 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 (lb/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 001 Benzene 71432 A 128 Yes 6.4 Toluene 108883 C 116 No 6 Xylenes 1330207 C 42 No n/a n -Hexane 110543 C 858 No 43 002 Benzene 71432 A 28.1 No n/a Toluene 108883 C 21.2 No n/a Ethylbenzene 100414 C 3.6 No n/a Xylenes 1330207 C 8.8 No n/a n -Hexane 110543 C 172.3 No n/a 003 Benzene 71432 A 6,844.5 Yes 342.2 Toluene 108883 C 5,168.1 Yes 258.4 Ethylbenzene 100414 C 868.9 No 43.4 Xylenes 1330207 C 2,146.6 Yes 107 n -Hexane 110543 C 41,959.6 Yes 2,098.0 004 Benzene 71432 A 139.9 Yes n/a Toluene 108883 C 458.1 No n/a Ethylbenzene 100414 C 33.8 No n/a AIRS ID: 123/9001/999 Page 10 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Public Health and Environment Air Pollution Control Division Xylenes 1330207 C 609.5 No n/a n -Hexane 110543 C 835.1 Yes n/a 005 Benzene 71432 A 383 Yes 19.2 n -Hexane 110543 C 1,204.5 Yes 60.2 006 Benzene 71432 A • 7.5 No 7.5 Toluene 108883 C 12.2 No 12.2 Ethylbenzene 100414 C 1.7 No 1.7 Xylenes 1130207 C. 4.5 No 4.5 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 VOC 0.135 lb/bbl 0.0067 lb/bbl E&P Tank 71432 Benzene 8.9 x 10' lb/bbl 4.4 x 10-' lb/bbl E&P Tank 110543 n -Hexane 0.0059 lb/bbl 2.9 x 10' lb/bbl E&P Tank Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. These emission factors were developed using sampling from Critter Creek 2-03H well site and E&P Tank. Point 002: CAS # Pollutant Weight Fraction of Gas Emission Factors Uncontrolled Emission Factors Controlled Source VOC 0.4618 33,600 lb/MMscf natural gas vented Eng. Calculation 71432 Benzene 0.0010 75 lb/MMscf natural gas vented -- Eng. Calculation 110543 n -Hexane 0.0063 459 lb/MMscf natural gas vented -- Eng. Calculation The emission levels in this permit for this point are based on the use of this tank to blowdown produced natural gas when the flare used to combust the natural gas is down at three (3) events per year and twelve (12) hours of venting through this tank per event at a maximum gas flow rate of 10,416.7 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. AIRS ID: 123/9001/999 Page 11 of 14 EOG Resources, Inc. Permit No. 11WE1462 Issuance 1 Point 003: Public Health and Environment Air Pollution Control Division CAS # Pollutant Natural Gas Composition (Weight %) Emission Factors Uncontrolled Ib/MMscf natural gas vented Emission Factors Controlled Ib/MMscf natural gas vented Source NOx -- 105.1 105.1 AP -42, Table 13.5-1, 1549 Btu/scf CO -- 571.7 571.7 AP -42, Table 13.5-1, 1549 Btu/scf VOC 46.18 33,616.6 1,680.8 Eng. Calculation 71432 Benzene 0.1029 77 3.85 Eng. Calculation 108883 Toluene 0.08 56.6 2.8 Eng. Calculation 100414 Ethylbenzene 0.01 9.5 0.48 Eng. Calculation 1330207 Xylenes 0.03 23.5 1.18 Eng. Calculation 110543 n -Hexane 0.63 459.8 23 Eng. Calculation 540841 2,2,4-TMP 0.0012 0.90 0.045 Eng. Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the August 10, 2010 analysis of a gas sample collected from the Critter Creek 2-03-H well. The controlled VOC and HAP emissions factors for point 003 are based on the flare control efficiency of 95%. Point 004: Note: The emission factor below may be used for both crude oil and produced water loading. CAS # Pollutant Emission Factors Uncontrolled Emission Factors Controlled Source VOC 0.104 lb/bbl -- AP -42 71432 Benzene 0.0007 lb/bbl -- AP -42 108883 Toluene 0.0023 lb/bbl -- AP -42 1330207 Xylenes 0.0030 lblbbl -- AP -42 110543 n -Hexane 0.0041 lb/bbl -- AP -42 The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) = 5.18 psia M (vapor molecular weight) = 33.46 Ib/lb-mol T (temperature of liquid loaded) = 524 °R AIRS ID: 123/9001/999 Page 12 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Public Health and Environment Air Pollution Control Division The uncontrolled non-cn eria repo able air pol u an CRP emission factors were calculated by multiplying the mass fraction of each NCRP determined in the pressurized oil analysis by the VOC emission factor. Points 005: CAS # Pollutant Emission Factors Uncontrolled Emission Factors Controlled Source VOC 0.262 lb/bbl 0.0131 lb/bbl PS Memo 09-02 71432 Benzene 0.007 lb/bbl 0.0004 lb/bbl PS Memo 09-02 110543 n -Hexane 0.022 lb/bbl 0.0011 lb/bbl PS Memo 09-02 Note: The controlled emissions factors for this point are based on the flare control efficiency of 95%. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 576 --- 520 51 Flanges 8 --- 24 4 Open -Ended Lines 9 --- 7 5 Pump Seals --- --- 2 --- Valves 56 --- 72 24 Other 35 --- 15 6 VOC Content (wt%) 3.5% 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%) 0.338% --- 2.43% - *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil SOil ervi 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. AIRS ID: 123/9001/999 Page 13 of 14 EOG Resources, Inc. Permit No. 11WE1462 E1462 Issuance 1 Public Health and Environment Air Pollution Control Division 6) In accordance with C.R.S. - -114.$, eact Air" Pol u an mission t4otice (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 of VOC Synthetic Minor Source of HAP PSD Synthetic Minor Source of VOC MACT HH Major Source Requirements: Not Applicable 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.wpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A — Subpart KKKK NSPS Part 60, Appendixes Appendix A — Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A — Subpart Z MACT 63.600-63.1199 Subpart PA — 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.html AIRS ID: 123/9001/999 Page 14 of 14 Construction Permit Application Preliminary Analysis Summary Section 1 — Applicant Information Company Name: EOG Resources, Inc. Permit Number: 11WE1462 Source Location: SESE Sec 28, T12N, R63W Source Name: Holstein 11-28H Equipment Description: Point 001- Four (4) 400BBL storage tanks for crude oil Point 002- One (1) 400 BBL emergency tank Point 003- One (1) Tornado Flare Point 004- Crude oil,and produced water truck loadout Point 005- One (1) 400 BBL fixed roof produced water storage tanks Point 006- Fugitive emissions AIRS ID: 123-9001 Date: Began reviewing: April 13, 2012 Review Engineer: Laura Strohkirch Control Engineer: Carissa Money Section 2 — Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3 — Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On May 23, 2011 Jake, who is also working on some EOG sites, e - mailed David Long about the flare calculations. The mole fraction VOC had been used instead of mass fraction VOC. This caused the emissions to be underestimated and with the correct calculations facility status could change. New calculations for this facility were submitted August 23, 2011 On what date was this application complete? March 11, 2011 original application was received. Supplemental data received September 14, 2011. Fugitives added to facility February 14, 2012 Page 1 Section 4 — Source Description AIRS Point Equipment Description 001 Four (4) above ground 400 bbl atmospheric crude oil storage tank. Emissions from these tanks are controlled with a Cimarron smokeless combustor unit (VCU) with 95% control efficiency. 002 One (1) above ground 400 bbl atmospheric emergency tank. This tank is used when there is a need to vent the natural gas from blowdowns of the flare rather than put it into the pipeline. There are no controls for this tank. 003 One (1) Tornado Flare that is controlling a separator. This is a 40' candlestick flare that is not enclosed and has been granted 95% destruction efficiency. 004 Crude oil and produced water truck loadout. 005 One (1) above ground 400 bbl atmospheric produced water storage tanks. Emissions from these tanks are controlled by a smokeless Cimarron Smokeless Combustor (SN: 1324431) with a destruction efficiency of 95%. 006 Fugitive emission leaks. 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? PM,o 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) PM,o 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 005: 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)? X Yes No Point 005: Are these produced water tanks located at a commercial facility that accepts oil production wastewater for processing? Yes X No Point 005: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 Rule? If so, submit Form APCD-105 Yes X No Section 5 — Emission Estimate Information AIRS Point Emission Factor Source 001 Source used E&P Tanks along with site -specific sampling to calculate a site - specific emission factor VOC E.F.= 0.13571b/bbl 002 Used maximum gas vented to atmosphere along with VOC weight fraction to determine a site -specific emission factor. VOC E.F.= 33,600 Ib/MMscf 003 Emission Factors for NOx, Sox, CO and PM10 came from AP -42 Tables 13.5- 1&2 Page 2 VOC emissions are based on a VOC weight -fraction VOC E.F.= 33,616.6 lb/MMscf 004 AP -42, Table 5.2-1, equation 1 005 CDPHE Emission Factors (PS Memo 09-02) 006 EPA -453/R-95-017, Table 2-4 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit (PTE) : 4 AIRS Point Process Consumption/Throughput/Production 001 175,200 BBL per year (146,000 x 1.2) 002 375,000 scf/yr or 0.375 MMscf/yr 003 250,000 scf/day or 91,250,000scf/yr or 91.3 MMscf/yr 004 200,750 BBLJyr 005 65,700 BBLJyr (54,750 x 1.2) 006 Equipment Type Gas Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) Water/Oil 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 Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/ThroughputlProduction Data Year 001 146,000 BBL per year while controls are in operation 2010 375,000 scf/yr or 0.375 MMscf/yr 2010 002 003 91.3 MMscf/yr 2010 004 200,750 BBL/yr 2010 005 54,750 BBL/yr 2010 006 Equipment Type Gas Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) Water/Oil 51 2010 Connectors 576 --- 520 Flanges 8 --- 24 4 Open -Ended Lines 9 --- 7 5 Pump Seals --- --- ! 2 --- Valves 56 --- 72 24 Other 35 --- 115 6 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 146,000 BBL per year while controls are in operation 375,000scf/yr or 0.375 MMscf/yr 002 003 91.3 MMscf/yr Page 3 004 200,750 BBUyr 005 54,750 BBUyr 006 Equipment Type Gas Heavy Oil (or Heavy Liquid) Light Oil (or Light Liquid) Water/Oil 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 Does this source use a control device? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Cimarron Smokeless Combustor (VCU) 95 003 01 Tornado, 40' Flare Stack, SN: N/A 95 005 01 Cimarron Smokeless Combustor (VCU), SN 5144 95 Section 6 — Emission Summary (tons per year) Point NO, VOC CO Single HAP Total HAP PTE: 001 0.03 11.9 0.18 002 - 6.3 - 0.08 (n -hexane) 0.1 003 4.8 1,534.6 26.1 20.9 (n -hexane) 28 004 - 10.4 - 0.42 (n -hexane) 1.04 005 - 7.2 - 0.4 (n -hexane) 0.5 006 - 2.4 - 0.1 (n -hexane) 0.1 Total (TPY) PTE: 4.83 1,578.38 26.19 29.84 Uncontrolled point source emission rate: 001 0.03 9.9 0.18 0.4 (n -hexane) 0.48 002 - 6.3 - 0.08(n -hexane) 0.1 003 4.8 1,534.6 26.1 20.9 (n -hexane) 28 004 - 10.4 - 0.42 (n -hexane) 1.04 005 - 7.2 - 0.8(n -hexane) 0.34 006 - 2.4 - 0.1 (n -hexane) 0.1 Controlled point source emission rate: 001 0.03 0.5 0.18 0.02 (n -hexane) 0.02 002 - 6.3 - 0.08 (n -hexane) 0.1 003 4.8 76.7 26.1 1.0 (n -hexane) 1.4 004 - 10.4 - 0.42 (n -hexane) 1.04 005 - 0.36 - 0.04 (n -hexane) 0.05 006 - 2.4 - 0.1 (n -hexane) 0.1 Total APEN Reported emissions: 4.83 97.76 26.19 1.67 (n -hexane) 2.81 Page 4 Section 7 — Non -Criteria I Hazardous Air Pollutants Pollutant CAS # BIN Uncontrolled Are"' i Controlled Emission Emission Rate emissions {Iblyr� repertahle9 Rate (Ib/yr) POINT 001 Benzene 71432 A 128 Yes I 6.4 n -Hexane 110543 C 858 No 42.9 POINT 002 Benzene 71432 A 28.1 No NA n -Hexane 110543 C I 172.3 No NA POINT 003 Benzene 71432 A 6,844.5 Yes 342.2 Toluene 108883 C 5,168.1 Yes 258.4 Ethylbenzene 100414 C 868.9 No 43.4 Xylenes 1330207 C 2,146.6 Yes 107.3 n -Hexane 110543 C 41,959.6 Yes 2,098.0 POINT 004 Benzene 71432 A 139.9 Yes NA Toluene 108883 C 458.1 No NA Ethylbenzene 100414 C 33.8 No NA Xylenes 1330207 C 609.5 No NA n -Hexane 110543 C 835.1 No NA POINT 005 Benzene 71432 A 383 Yes 19.2 n -Hexane 110543 C 1,204.5 Yes 60.2 POINT 006 Benzene 71432 A 7.5 No 7.5 Toluene 108883 C 12.2 No 12.2 Ethylbenzene 100414 C 1.7 No 1.7 Xylenes 1130207 C 4,5 No 4.5 n -Hexane 110543 C 252 No 252 Note: Regulation 3, Part A, Section Il.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 002 01 VOC & HAP's State -only requirement Site -specific gas analysis 003 01 VOC & HAP's State -only requirement Site -specific gas analysis 006 01 VOC, HAPS State only requirement Site -specific gas analysis 006 01 VOC, HAPS State only requirement Hard component count Section 9 — Source Classification Is this a new previously un-permitted source? (Points 001-005) X Yes No What is this point classification? True Minor Synthetic Minor Major Point 001: Four (4) above ground 400 bbl atmospheric crude oil storage tank X Point 002: One (1) above ground 400 bbl atmospheric emergency tank X Point 003: One (1) Tornado Flare X Point 004: Crude oil and produced water truck loadout X Point 005: One (1) 400 BBL fixed roof produced water storage tanks X Point 006: Fugitive VOC emissions X 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 X 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? For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, 111.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Air Quality Standards (NAAQS)? If "yes", for which pollutants? Why? Yes X No Page 6 AIRS Point Section 12 — Regulatory Review Regulation=1 - Particulate Smoke, Carbon Monoxide and Sulfur Dioxide 001-006 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. Requlation 2.- Odor 001-006 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. Requlation 3 - APENs; Construction Permits Operating Permits, PSD 001-006 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 for points 001-006 since emissions exceed 2 tons per year VOC) 001-006 Part B — Construction Permit Exemptions Applicant is required to obtain a permit for points 001-006 since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold (Reg. 3, Part 8, Section ll.D.3.a) 005 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 attainment area, therefore, not subject to RACT. However, operator is using 0.6 (submerged, dedicated normal service) for its saturation factor. Regulation 6 - New Source Performance Standards ;. 001,002,005 NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No 003,004, 006 none Regulation 7:- Volatile Organic Compounds 001,002,005 XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is located in an attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since these are not condensate storage tanks 003,004, 006 None Regulation 8 — Hazardous Air Pollutants, 001, 002, 005 MACT EEEE: Organic Liquids Distribution • This source is not subject to MACT EEEE because it is located at a "production field facility" as defined in 40 CFR 63.761 (located upstream of the natural gas processing plant). Page 7 MACT HH 001,002 • This source is not subject to MACT HH because it is not located at a major source of HAP. 003,004, 006 none 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 E&P Crude Oil Storage Tanks 3.230 lb/1000 gal throughput VOC No Site -specific 95 0.02 lb/1000 gal throughput Benzene No Site -specific 95 SCC 40400312 — Fixed Roof Tank, Crude Oil, working+ breathing + flashing losses Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (%) 002 01 Emergency Tank 33,600 lb/MMscf VOC No Mass Balance NA 75 lb/MMscf Benzene No Mass Balance NA 459 lb/MMscf n -Hexane No Mass Balance NA SCC 31000299- Natural Gas Production: other, not classified Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (%) 003 01 Tornado Flare 33,616.6 lb/MMscf VOC No Mass Balance 95 105.1lb/MMscf NOx No AP -42 NA 571.7lb/MMscf CO No AP -42 NA 0.657 lb/MMscf SOx No AP -42 NA 77 lb/MMscf Benzene No Mass Balance 95 56.6 lb/MMscf Toluene No Mass Balance 95 23.5 lb/MMscf Xylenes No Mass Balance 95 459.6 lb/MMscf n -Hexane No Mass Balance 95 SCC 31000205 — Flares (at gas production facility) Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (%) 004 01 Crude Oil and Produced Water Tank Truck Loadout 2.47 lb/1000gal VOC No AP -42 NA 0.016 lb/1000 gal Benzene No AP -42 NA 0.098 lb/1000 gal n -Hexane No AP -42 NA SCC 4060132: Crude Oil: Submerged Loading (Normal Service) Page 8 Point Process Process Description Emission Factor Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (%) 005 01 E&P Produced Water Storage Tanks 6.2381 lb/1000 gal throughput VOC No CDPHE PS Memo 09-02 95 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 Point Process Process Description Pollutant / CAS # Fugitive (Y/N) Emission Factor Source Control (ova) 006 01 Fugitive VOC Leak Emission VOC Yes EPA -453/R-95-017, Table 2-4 NA SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14 — Miscellaneous Application Notes AIRS Point 001 Crude Oil Tanks These tanks contain oil with an API gravity less than 40 degrees. EOG used E&P Tank to estimate the flash emissions off this tank battery. From E&P Tank- uncontrolled ton/year= 9.9 TPY VOC VOC=(9.9 TPY)*(20001b/ton)/(146,000 bbl/yr)= 0.1357 lb/bbl VOC or 3.230 lb/1000 gallons AIRS Point 002 Emergency Tank Gas going to the flare would be routed to this tank in case of a flare outage. The gas is vented to atmosphere from this tank. The APEN was submitted with worse -case scenario calculations. This consists of 3 upset conditions in a 12 month period. Each instance of upset conditions was estimated to be 12 hours in length. Max gas vented to atmosphere= 10,416.7 scf/hr Molecular wt. of gas= 27.6 lb/lb-mole VOC fraction= 0.4618 379.4 scf/Ib-mole VOC= 10,416.7 scf/hr*( 27.6 lb/lb-mole)/(379.4 scf/Ib-mole)*0.4618= 350.1 lb/hr VOC Using the 3 upset conditions at 12 hrs per condition: 350.1/hr*(12 hr/event)` (3 events/yr) / (2,000lb/ton)= 6.3 tpy VOC VOC E.F.: 6.3 ton/yr *( 2,000Ib/ton)/(0.375 MMscf/yr)= 33,600 lb/MMscf Page 9 AIRS Point 003 Tornado Flare The tornado flare is controlling gas coming off the well since there is no pipeline available in the area at this time. EOG will continue to flare gas until a pipeline is available. Emissions were calculated using VOC wt fraction. (scf/hr) * (Ib/Ib-mol) * (% fraction from sales gas analysis) / (379.4 scf/lb-mol) = lb/hr * (hr/yr)./ 2000 lb/T) = TPY Emission factors for NOx, CO, and PM10 came from AP -42, table 13.5-1 Emission factor for SOx also came from AP -42 and is based on 100% conversion of sulfur to SO2 at 2000 grains/MMscf VOC E.F. = (1,534.6 TPY * 2000 lb/T) / (91.3 mmscf/yr) = 33,616.6 lb/MMscf HAP's Emission Factors: Benzene = (6,844.5 Ib/yr) / 91.3 MMscf/yr = 77 lb/MMscf Toluene = (5,168.1 Ib/yr) / 91.3 MMscf/yr = 56.6 lb/MMscf Ethylbenzene= (868.1 Ib/yr) / 91.3 MMscf/yr= 9.5 lb/MMscf Xylenes= (2,146.6 Ib/yr) / 91.3 MMscf/yr = 23.5 lb/MMscf n -hexane = (41,959.6 Ib/yr) / 91.3 MMscf/yr = 459.6 lb/MMscf AIRS Point 004 Truck Loadout of Crude Oil and Produced Water Converting the Ib/1000gallon factor to lb/bbl AP -42: Chapter 5.2 Equation 1 L = 12.46*S*P*M/T L = loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T = temperature of bulk liquid loaded [deg. R] S 0.6 Submerged loading: dedicated normal service P 5.18 psia M 33.46 lb/lb-mole for gasoline with RVP = 11.5 T 523 deg. R (64 deg. F) L 2.471b/10^3 gal Annual requested Throughput 8431500ga1/yr Annual requested VOC emissions 208001b/yr 10.4tpy Page 10 AIRS Point 005 Produced Water Storage Tanks Operator originally requested this point to be a General Permit, however, having the general permit emission limit of 39TPY for VOC would have made them a major source so operator requested that the point be added to the facility -wide construction permit so actual, controlled emissions would be accounted for instead of the general permit limit. State -Developed Emission factors in lb/1000 aal are: County Produced Water Tank Default Emission Factors (lb/1000 gal) VOC Benzene n -Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, Douglas, Jefferson, Larimer and Weld 6.2381 0.1667 0.5238 The APEN states that the tanks contain less than 1% by volume crude oil on an annual average basis which qualifies the source for the categorical exemption (Regulation 3, Part B, Section II.D.1.m). However, this source will be permitted because if it was not contro led, the overall permitted VOC emissions would be greater than 100 TPY and become a major facility. The operator has requested synthetic minor status and accepted Federally enforceable controls, so this point will be included to ensure synthetic minor eligibility. AIRS Point 006 Fugitive VOC emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (APEN threshold) and the total facility is greater than 5 TPY (permit threshold). When reviewing calculations for a similar facility in non -attainment, another engineer working on these sites noticed the fugitive emissions were calculated incorrectly. These errors triggered fugitives in attainment facilities to be permit -required (increase from 1.5 TPY to 2.4 TPY). EOG submitted APENS for the fugitive emissions on 2/14/12. Points 001-006: No monthly limits will be put in the permit even though this is a synthetic minor source. After discussing this source with Chris Laplante 3-8-2011 it was decided that since production at an E&P site is not steady enough to impose those kinds of limits. Compliance on a monthly limit may not be possible, while a yearly limit could be. Page 11 Air Pollutant Emission Notice (APEN) — and — Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTER T0-TT-E0-TT0Z-N3dV-T00-T006-EZT Current Status (Check ll that pply) AIRS ID #1: 1�1 {/x4001 /OOI Reason for APEN Submittal (Check all that apply) only° to existing sources for coverage under general permit request for individual permits: for or Modification of an individual permit amendments t>[ 1 t. 2( AnD no. GPOI stational :`0I/`" ' • APEN update ,1 New or previously nreported battery - GP01 I I WE)N(a ). • Modification • Previously grandfathered batter)? • Registration • Synthetic minor facility & cancellation • Located in the 8 -hr Ozone Control Areas Al Application permit ❑ Registered under general permit no. Permitted under individual permit: • Administrative ■ Other: For individual permit applications, check if you wants: analysis conducted by the Division of the permit prior to issuance • A copy of the preliminary ■ To review a draft Company Name9: EOG Resources, Inc. OGCC Operator #: 27742 Mailing Address" : 600 17th Street, Suite 1000N - - david_long@eogresour City: Denver State: CO Zip: 80202 E-mail: ces.com Contact Name: David Long. Phone: 303-262-9448 Fax: 303-262-9449 Tank Battery Namell: Holstein ll-28H Total tank services: Control Efficiency PTE calculations: Operational21 emergency Number of tanks: capacity [bbl]: 2010 4 Location12 (QQ Sec. Twp. Range.): SESE S 28,T1 IN,R63 W County: Weld 1,600 (400 ea) Calendar year for which "Actual" data applies'': Control Description's: Cimarron Smokeless 2010 Year(s) tank(s) were placed in combustion unit [VCU]) Combustor (vapor 16: 95% Condensate Throughput's [bbl/year] Requested's: . Actual�0: Other equipment at facility22: VCU, flare, heater .363;600 It] (a, or:. Maximum for While Controls H2O tank (1), 4&t060 t15 :9 365000 14 to, (Dz2 363-000 t4(0, 003 treater (I), line heater (1), produced blow down tank Comments: Due to the low gravity of the oil, the tanks do not qualify for GP01 coverage. Therefore, an individual permit is being requested. Estimated emissions at throughputs listed above. Use N/A for requested throughput/ emission Check if site -specific Requested Uncontrolled" N/A values unless emission factors provided Emissions18 Controlled" N/A requesting an individual to calculate Actual Emissions�0 Uncontrolled" t c:( "244 permit emissions23. Controlled" O 1 12 • Check if the Division is to calculate emissions. /VA Emission Factor Pollutant24 [Ib/6bl] VOC [tons/year] O.V,35I 04335' Battery PTE2' lI/ 29:2. NOx [tons/year] N/A O..33 047 CI 04&:13:7 C,Oj'O07 CO [tons/year] N/A U. i ¶( tl:d6 C7. IV03fi 0.. i1? 0:36 Benzene [lbs/year] - qa 3-14.0 i`'15.70 n -Hexane [lbs/year] ea 2;-1-08-0- q.,). tilts"° Wells serviced by this tank or tank batteryrs API #: 05-123-30920-00 Name: Holstein 11-28H Well Well Well Well Well Welli t; Well'? G Newly Reported API #: Name: ■ Newly Reported API #: Name: ■ Newly Reported API#: Name: • Newly Reported API #: Name • Newly Reported API #: Name: - ■ Newly Reported API #: Name: ■ Newly Reported The signature below indicates that I have knowledge my knowledge and belief. If this is a r3 s ation in full compli.. -. . : 'ab general of the facts herein set forth and that the same are true, accurate, and complete to the l}iest of for coverage under general permit GPOI, I further certify that this source is and will be operated pemut GP01. Signature of Let - . -' uth • -> edPers. • not a vendor or consultant) - Date y.-r RI Da on on_ i Division Environmental Manager Cc T .'{e o ' -rson Signing Above Official Title Submit this form, along with $152.90 for each Colorado Department of Public Health and Environment filing of up to 5 tank battery APENS. Include Air Pollution Control Division, APCD-SS-BI 1 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver, CO 80246-1530 r: j For information call: (303) 692-3150 FORM APCD-205 awlat . oc e bnn5 Page 1 of 2EOG Holstein 11-28 FormAPCD-205-E&PCondensateTankAPEN.docx a. O cr Ce d a FU. q o p Q Ca • 0 d+ 0 -) U i O Ce c. W U F O O V▪ D Ut FTC O Pr APCD has already assigned a permit # & AIRS ID] ' [Leave blank unl Section 02 — Re Section 01- Administrative Information s O T 0 o - 0 4 a E 4 W v o c h W c u a T e m. 'C .E • pp o e o. 3 a h d F ° E c .c O i a O V V V Y 4 N in Cte c 3 w o �". O C OVp m 7. GE G e N U .c ^O a ❑ 0 a) V 0 s, m ' .4 a. • 3 v d d H c °i g m a c 2 • L • V 0' Z 4 r+ T U i- _- w O O' ''i C w 3 L u .71 y 6 0 a .�-1 ti ° rt.'� m 0 i d w v O i v PA • 3 m cu ▪ m m v > > C ❑ O z z a❑❑ z z❑❑ a.. 4 Si ❑ ❑ ❑ ❑ '¢5z e a 4 0. -❑ L • O E en O 0 -o U U zU Source Name: Holstein 11-28H rat 'rat Denver, Colorado 303-262-9448 Phone Number: G 0 Q Person To Contact: Section 03 — General Information the projected startup date is: For new or reconstructed source ro 0 N p tiN operation began on: General descripti 0 p o W Vl i s� V ^ _ m m en C N N N arm si 4 - 2 atq,b o 0 o -as W p m ,.2 us s P. Q N 0 p I. F Q CCI y Vto cn 3 ooi u.x --.E }a.. q v a) C 0 j. Q1 y F ' y 4 `' 00,a .gym °qd Q o y a T o o f u e o 0 R� Av VN� 06 > w E U a U 4 .- :. O O p Ui Q 9 L O U Oin .O. rI O t U p y a c? .c i 'oO a q m E " o A o > a a = 0.1 j'] K4 O O a M V p t. o° 73. H v,. �" UdeQ w Qrn :/ Y ❑ meat Information & Material Use a) W /1VIanufacturin Section 04 — Processin Serial No.: 28677 Model No.: EOG #4146 S O 0 • a z U O C G m y � o0 O Lo o 0. .a 4 P. pia 'Si v w w 0 a 0, O 0 o 0 c c 0 0 O O O 0 p -0 V V U U ❑ ❑ T w X s 0 5 70 Eg • m O '« a o cad m ? O 9 tr E> O v w a v m � ▪ O II y .+ a) d a) f additio O N a a FORM APCD-200 123-9001-002 -APEN-2011-03-11-01 E C V W iW V Z cen k-4 w L�L.. ® C a .0 E L a a z m R CO ,t Psc de O N 2 a 0 O u 00 Emission Source AIRS ID: co N co co m cn 00 y m 0 en 0 en oo N Vi e U 0 e .5 • y g • ca u LJ J ❑ • N C h. 0 ✓ ry u co,z0 0 0 0 Exhaust Opening Shape Moment & Fuel Consumption Information Section 06 — Combustion E Manufacturer: Company equipment Identification No w A: -o 3 d U Q1 imitations. Requested level should consider process growth over the next five years `Requested values will become pen Section 07 —Emissions Inventory Information & Emission Control Information 0 N CG a CO G CO r *a • .0 0 E @T w m zO w= O Q V • t V O CO T CO E qY '00 O 0 CO 0 ti ` u b m o o E_ o O O O O ..p0.' 0 II ' 0 0' 3-5 .6 70 3 n-' 0'0 O U 0 d JO U 0 H c�. O cep z U o o CO o .15 C A C I- 0 m L E Ca Ca CO 0. u CO L 0 Nm CO L U C z A o. 492 U U d a) cM (ti 0 `id" _NH CC id o Y % u CI i W C cr: co O LZ) F' 0 a 0 0 ET FormAPCD-200-Ge 00 N N AIR POLLUTANT EMISSION NOTICE (APEN) & Application for Construction Permit — General Emission Source AIRS ID: 3 Section 02 — Re Section 01 — Administrative Information mit or newly reported emission source Company Name: EOG Resources, Inc. aza .) ge company name Change fuel or equipment N IC Transfer of ownership Change permit limit Request to limit HAPs with a Federally enforceable limit on PTE O E-) . O a y O E o w a .N R R E p 8. w o o 3 0 w ° c s .9 °R 0 an p o O O fl P. Sy A Y R p v W o t � y R ?' C an Z ya N O O 0 a) n n R •0-0 U N 600 17th Street, Suite 1000N Mailing Address: Denver, Colorado 0 V 0 en 0 GO 0 C of 1.3 PI I Q 9 U N R py) 0 ea — ° A 0 - 5 w w Section 03 — General Information ew or reconstructed sources, the projected startup date e N N a) 3 v N ontrol the associated gas production stream until a pipeline becomes available. The Tornado flare is used to O a) C C E o. O o oo to a to N tom- 'z ° .7.-). - IS rn cn n g w N N N ° a R C N°r �� o QN.DO O'O O^4°. vi to N 0 L Nt Q' N fit: v v .3 0 k o Q 0Eo o w° f m E '� b° al w a y o w a ¢ En .° a d ill oo gi O R 3 ° T o E O . W o a n C o Cc a g a' :' s m m y s. o p tE G A R -c o o u �o 0 o y N 'E EA 7 w a R L N CO U¢ a N O E Y U n 0. x O Q C g, C O 0 °,8) d ' w iii . u, o > > a p°. -' Z .9 a° d F v a a z a .0 he. 02 ❑ /Manufacturin Section 04 — Processi F • 0 to Model No.: 4W Flare Stack O." U p6 e N ^ at 9 4 O O. O co co v ° a O A m b 9 w 00 o 4 6. co o O c o O O 0 0 A A .0 .G U ❑ ❑ O 0 on O o y a m `n a ca 0 CV a C o F a — Cr v o 0 mcr a0. y O ro E a a ?..4 p 0 v � 0, a d > d 0 m °' N 0 00 N w FORM APCD-200 Emission Source AIRS ID: Permit Number: Lion Information ment & Fuel Consum Section 06 — Combustion Foul z h Manufacturer: Company equipment Identification No.: at 0 z N N N O Q Tel N p a. O at .C 1,549 Btu/scf (HIIV) a ai a • Q. LP v 0 0 m 0. 0 0 .0 a 0 a 0 a) O. E 0 .OO c d c 0' z Section 07 —Emissions Inventory Information & Emission Control Information AP42 Tb1 13.5-1 4-4 y en O O AP42 Tbl 13.5-1 0 U O AP42 Tbl 13.5-1 o v .C' O ei a- R d at 0 O 0 .O p 0 WO L. z o V o o- o m o T N R E `n ci 0 `0 0 at o d V V t 0 O ro 0 0 _ U Q n ,a 4 E e m a c m } O O F O^ m a o c 0 0 or 0° — r O M 0 hV m M 0 R Ge a` a e N T In oe a, F w z O a y 0 qc i m " v: w y ≥ a, at. 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U 0 Chemical Name Benzene Toluene - Xylenes n -Hexane Chemical Abstract Service (CAS) Number 71432 108883 1330207 540841 U) a) To a) cu � N O O t6 �> r C v W Q C O U 0 0 0 a) a) >- C a) CO 0 C a) U) C c) N orting Scenario (1, 2 or a) CO Ca 0 Dam Q 0 CID N 0 Q >, CO ignature of Person Le 0) C 0 - J ✓ ec 0 C Q a) CA CO a) 0 CO CO 0 >� 0_ cn 0 m N 0 C0 0) a) C 0 L 9— O a) E N z Form Revision Date; December 4, 2006 S O e at 'O Ct O t o A A -W Q ^:4 � xt m .. E a S 9 m QI O: O 0 w U 0 a7 V U Boa f E C .a a u°' 0 r•m a , dz 05 a o re. at ov m W 4 0 V z 0 O1� v a.-; $.1) �a I -I A c/j P AIR POLLUT O nested Action (Check applicable request boxes) Section 02 — Re Si 0 y a 0 E Ce i. 0 0 Ce p 0 a L W z F d z 0 O T ❑ o O 0 4 a ^ a at 9 a a — at. cn 0 4 0 4p 0 000 a N U 0 0 `p a. 3 eo e o w a Q m `m h _ e m - z ? U .. 0 0" C On ^+- Li 3-I a a C 0 00 2, m a 0 0 Cm C O ❑ ❑ Change process or equipment E 0 a u L Va i 0 - W ck the box below that ® ❑ ❑ ❑ o 0 0 U zcn EOG Resources, Inc. 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L m w at U 9 O O a< b " U to y T m 4 T T. 0 O 4 b L LL C O h N 123-9001-004—APEN-2011-03-11-01 FORM APCD-208 AIR POLLU Permit Number: Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) Section 05 — Stack Information (Combustion stacks must be listed here) 5 o `o N CC Go CA ©a C M m N N V R A 5 0 I^ O5 O V • o G TS • Q D U U t aO W d u • N Ca Ct u � -4 � U1 .0 w N O 4 0 • cp U ct ct Section 07 — Control Device Information E 4a a 0 1E' U a O a O Ct E w a L 0 a a a O E CO a O U Ca Data year for actual calendar year emissions below & throughput in Sec. 04 (e.g. 2007 Emission Factor Documentation attached O 0 5 U 0' N A 2 b N N U 0 U e O O 6 C V7 N O O d N '0 C 0 m W 0 4- 0 0a a O A 2 1 az. ea O 6 O O G 0 - e N N 1< x N 8 O m R 0 O Gip 0 5 .0 U C 0 PO C C 7 Section 02 — R W individual permit or newly reported emission source RI 0 C - M e a O 0 V) U U o a U O Section 01— Administrative Information EOG Resources, Inc. Company Name: 051 OIL Change permit limit en In U a N 600 17th Street, Suite I000N a Q ❑ a On `a d o ^ O R .N 0 0 y N y Li. H 0 0 • w ry o F u o a a 0 O DI 00 a 0 0 0 ON c 0 u .L. 00 :g4 >. u O ca L 9 a O. C - N C U W ca a 0 — a h .a e o• z ❑ ❑ 5 0 s.z ❑ '4'� Denver, Colorado 303-262-9448 Phone Numbe 0 Person To Contact: 303-262-9449 z w david_lon ggeogresources.com y et Q a Section 03 — General Information ti zz 0 z up 0P >r o 0 0 ® ❑ ❑ ❑ o c 0 N F O E0 N -8 N A m N L v u i3 m O 2 a a U a) N to; a 0 ' o 3 v a u 0 0 0 m VO a m '.0 co O O N O a o N O 00 y h a �. U y 0 0. O y n ` a 0 i a @ acaa�¢y- c w 4 o A A 0'O C •aI 0. P-• 0 E 0 78 A 0. N IO y d In d' ^ `co in ^-. o 74 G W bO0" Z.w y f m :1 p U % N N N E Hill ill CS' 47 R m o c 0 0 boo N u 0 is C .v'. su.06 _W,...' a. m U 7 ,5o A ▪ 0. 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Z O L O 0 .Vu y¢ o cc a.U. 801« Q 9 m" s W r n C C x c' W z d ?, I z C r a w G m .> as P .0. QaC°>i O. A. .. 0 x x ti O 0 0 0 0 O or V P F4 CU ❑ ❑ S a ❑ ❑ e El El ID 'a=z W N N N C 0-o 0 c/3 0 0 > U a� U P z00 00 N FOG Resources, Inc. Holstein 11-2814 9 E T 8 a 0 co U SE/SE, Sec 28, TI1N, R63W Source Location Denver, Colorado 303-262-9946 Curtis Rice U " 0 U 0 N a 303-262-9449 curtis_rice@eogresources.com E-mail Address: Section 03 — General Information m o" ay LL,z ci nu a.,2U a " P o o ^ C b➢ P O O A h 0 U O 3 0 >' O 0, o ic•> C > 3 co o ro 0 T o >a. 0 0 'd m O o o a 0 O o' ro y L w a C c en CO CO 0 G O O O y C.1 v M O E v o O C O Nw z Po 471 O ax s:5 5 P C a ti o u a 0 ' o A e o. = m E .o o O. m G G n. a (� A E m y o " .. Ts L L N 'I O 4,,-`I+ �. E a,� U w' o U .0 O L S to v C ^ y OQccLo O o2 g C N O d N ,2 0 =L6Uu a, 7,d z.� C o W w p F W Pa. C)<eQ fa, <a << Information 0 CC C Section 04 —Re ❑ ❑ o. cn co a cn z z U V 4) 0) 7 'P 5 G 4 d os 0 L L P 40 CFR Part 63, Subpart FE?. List any other NSPS or NESHAP Subpart that applies to this equipme Section 05 - Stream Constituents ❑❑ n -Hexane (wt.Vs) cern m C e -- 'z M N O o Xylene (wt. %) O O c Q z 0 O o o e O 0 c Ethylbenzene l (wt. %) cc O o o Q z O S d co e o C .O r 01 O o 6 Z. O O O e zi Benzene (wt. "/0) N CO e -_ 'z o o o c ca 0 O e 3 O o Q z N o o Stream Heavy Oil' (or Heavy Liquid) Light Oil (or Light Liquid) .I .- fe U C N V C A a 0 0 O O R .Pa 6 O. m 0 0` a O O a a oter V 00)) O O0 0 O 0 .0 O .O U U 0 •IC 79 G 0 P t P. 00 en G o a 0 V M �r ro qV 0. q C a 0 en a E O N 0 P.bi FORM APCD-203 123-9001-006-APEN-2012-02-14-01 orient Leak Emissions E O Emission Source AIRS ID: Permit Number: & Control Informa Q R Section 07 —Leak Detection & Re Section 06 — Location Information (Provide Datum and either Lat/Long or UTM HN O No LDAR program h 10,000 ppm/ leak de If LDAR per NSPS K h n e Section 08 — Emission Factor Information E 0 m w .0 U N a N b N N n N N O Actual Count ® Estimated Count 0 N 00 a U, n E a' cr 0 c U eq C 0 LC 0 H 0 N type of service used to calculate the "Actual Calendar Year Emis II be the aclu Section 09 — Emissions Inventory Information & Emission Control Information Data year for actual tale ❑ Emission Factor Documentation attached r0 e U H 0 0o a U L T C i N V N n N N H C N. 0 Co 0 C C C O U O 0 H 0 0 a C 0 C x 0 c L 0 0. 'O. C 9 C W a CC 0 m FG C 0 z U 0. Q V Cl a ry G 0 a .'o E N o. o C 0 y 0 v T f 0 O' V N Sr. Environmental S Curtis Rice C) licant Ce I-28FI FormAPCD-203-FugitiveComponentLeaksAPEN.doc EOG Holstein Hello