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Home My WebLink About20142733 ,A, coAE COLORADO LI Co Department of Public :srHealth 8 Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St RECEIVED PO Box 758 Greeley, CO 80632 SEP 0 2 2014 August 28, 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On August 31, 2014, the Air Pollution Control Division will publish a public notice for Bonanza Creek Energy Operating Company, LLC - Antelope P-17 Production Facility, 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 Et Environment APCD-SS-B1 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 t j,U aLa et: pL,iTu)I Mti 2014-2733 9-Io-(44 9Js CDPHE Public Notice Of A Proposed Project CO % Or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company, LLC - Antelope P-17 Production Facility - Weld County Released To: The Greeley Tribune On: August 28, 2014 Published: August 31, 2014 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: Bonanza Creek Energy Operating Company, LLC Facility: Antelope P-17 Production Facility Oil and natural gas exploration and production facility NWNE Sec 17, T5N, R62W Weld County The proposed project or activity is as follows: The applicant proposes to increase the throughput an exploration and 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 III.C.1.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 12WE2919 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 https://www.colorado.gov/pacific/cdphe/air-permit-public-notices 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-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us A® COLORADO STATE OF COLORADO OF COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT tea% AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 6924150 :87g s* CONSTRUCTION PERMIT PERMIT NO: 1 2WE2919 Issuance 2 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Antelope P-T-17HZ Tank Battery, located in NWNE Sec 17 T5N R62W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point Four(4) 400bb1 and Six (6) 500bb1 crude oil storage tanks. The emissions from the tanks are controlled by one (1) Tanks 001 Cimarron Energy 60" ECD Flare (SN:5601709) and five (5) Leed Fabrication L30-0010 Flares (SN: 21297, 21296, 20924, 21295, 21294). Control efficiency is 95% Two (2) 400bb1 tanks and two (2) 60bb1 concrete vaults used PW Tanks 002 to store produced water. The tanks are controlled by flares at 95% control, and the vaults are uncontrolled. One (1)Arrow Engine Company, Model A-62, Serial Number To Be Determined, natural gas-fired, naturally aspirated, El 003 4SRB reciprocating internal combustion engine, site rated at 80 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system. This emission unit powers a pump jack. Truck 004 Truck loadout of condensate. Emissions from the loadout Loadout are not controlled. Fugitive Emissions from 3 well heads, 3 heater treaters, 6 FUG 005 flares/combustors, 10 condensate tanks, 4 produced water tanks, 3 engines, and 3 pneumatic pumps. AIRS ID: 123/9A53/001-006, 010-012 Page 1 of 23 NGEngine Version 2012-1 Colorado Department of Public Health and Environment Air Pollution Control Division Facility AIRS Description Equipment ID Point Pneumatic One(1)water transfer pump, and one(1) heat trace Pumps 006 circulation pump, both Sandpiper G1 F models, each rated at 600 scf/hr. Sep-2 &Sep-3 010 Two(2) High/Low pressure separators controlled by six(6) enclosed flares. P-3 011 One(1) Sandpiper G1 F pneumatic pump used for water transfer FL-1 012 One (1) Emergency Flare Point 003: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow Engine Company A-62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 006: This pump may be replaced with another pump in accordance with the provisions of the Alternate Operating Scenario (AOS) in this permit. 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 sect), 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 Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdohe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (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 in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, II.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) AIRS ID: 123/9A53/001-006, 010-012 Page 2 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division 4. Points 003 & 006: The following information shall be provided to the Division within fifteen (15) days after issuance of permit. • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, 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: Facility AIRS Tons per Year Equipment ID Point NO VOC CO Emission Type Condensate 001 --- 10.8 2.4 Point Tanks PW Tanks 002 --- 0.8 --- Point El 003 2.16 --- 3.71 Point Truck Loadout 004 --- 27.4 --- Point FUG 005 --- 20.3 --- Fugitive Pneumatic 006 --- 4.78 2.44 Point Pumps Sep-2 &Sep-3 010 1.0 18.0 5.2 Point Pneumatic 011 --- 2.4 1.3 Point Pump FL-1 012 --- 1.2 --- Point See "Notes to Permit Holder"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 annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. AIRS ID: 123/9A531001-006, 010-012 Page 3 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division 7. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit(Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID Condensate 001 Enclosed Flare VOC, HAPs Tanks PW Tanks 002 Enclosed Flare VOC El 003 Non-Selective Catalytic Reduction NOx and CO Pneumatic 006 Enclosed Flare VOC Pumps Sep-2& 010 Enclosed Flare VOC, HAPs Sep-3 Pneumatic 011 Enclosed Flare VOC Pump 8. Point 005: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended gas analysis, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. PROCESS LIMITATIONS AND RECORDS 9. These sources shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Equipment ID Point Limit Condensate 001 Throughput of Condensate 232,870 Tanks BBUyr PW Tanks 002 Throughput of produced water 118,260 BBUyr El 003 Consumption of natural gas as a fuel 6.30 MMscf/yr Truck Loadout 004 Condensate Loading BB04� Pneumatic 006 Venting of natural gas used to drive two 10.6 Pumps pneumatic pumps MMscf/yr AIRS ID: 12319A531001-006, 010-012 Page 4 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division Sep-2 &Sep-3 010 Throughput of natural gas 15 MMscf/yr Pneumatic 011 Venting of natural gas used to drive two 5.3 Pump pneumatic pumps MMscf/yr FL-1 012 Throughput of natural gas 2.6 MMscf/yr Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. Points 003,004,006: The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. Visible emissions shall not exceed twenty percent(20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. &4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. Point 004: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 14. This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 15. Point 005: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. AIRS ID: 123/9A53/001-006, 010-012 Page 5 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division i. For leak screening, auditory/visual/olfactory inspection (AVO) will be performed on a semi-annual basis. ii. For each leak found in the AVO inspection, a gas detector shall be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO screenings, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. OPERATING & MAINTENANCE REQUIREMENTS 16. Points 001-003, 006, 011: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 17. Point 005: Within one hundred and eighty days (180) after issuance of this permit, the owner or operator shall complete the initial extended gas analysis of gas samples that is representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis 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 analysis and emission AIRS ID: 123/9A53/001-006, 010-012 Page 6 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division calculations to the Division as part of the self-certification process to ensure compliance with emissions limits. 18. Point 005: Within one hundred and eighty days (180) after issuance of this permit, the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 19. Point 003: This engine may be 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. 20. Point 005: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATE OPERATING SCENARIOS 21. Point 006, 011: These pumps may be replaced with a like-kind pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like-kind replacement pump shall be the same make, model and capacity as authorized in this permit. 22. Point 006, 011: The owner or operator shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 23. Point 006, 011: All pump replacements installed and operated per the altemate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 24. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30'" whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per AIRS ID: 123/9A53/001-006, 010-012 Page 7 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. 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 owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 25. 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). 26. MACT Subpart 7777 - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of that Subpart on the date as stated in the rule as published in the Federal Register. (Reference: Regulation No. 8, Part E) 27. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS: 28. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AIRS ID: 123/9A53/001-006, 010-012 Page 8 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division 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 self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 30. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator 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 owner or operator or owner or operator'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 owner or operator, or the Division revokes a permit, the owner or operator 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. AIRS ID: 123/9A53/001-006, 010-012 Page 9 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division By: 11 t[f/ f t Stuart Siffring Permit Engineer Permit History Issuance Date Description Issuance 2 This Issuance Modification to add points 001, 002, 010, 011, 012, and change limits associated with points 004, and 005. Issuance 1 4/16/2013 Issued to Bonanza Creek Energy Operating Company LLC AIRS ID: 123/9A53/001-006, 010-012 Page 10 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 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 owner or operator 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 complete 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 owner or operator 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/100102aacccommonprovisionsreq.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. Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate(lb/yr) (Ib/yr) Benzene 71432 A 3564 Yes 178 Toluene 108883 C 2162 Yes 108 Ethylbenzene 100414 C 134 No 7 001 Xylenes 1330207 C 535 Yes 27 n-Hexane 110543 C 23722 Yes 1186 224-TMP 540841 C 1006 Yes 50 Benzene 71432 A 828 Yes 41 002 n-Hexane 110543 C 2602 Yes 130 Formaldehyde 5000 A 128 Yes 128 • Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 003 Acrolein 107028 A 15 No 15 Benzene 71432 A 9 No 9 1,3-Butadiene 106990 A 4 No 4 Toluene 108883 C 3 No 3 Benzene 71432 A 719 Yes 719 004 Toluene 108883 C 1530 Yes 1530 AIRS ID: 123/9A53/001-006, 010-012 Page 11 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division Ethylbenzene :•_., - , C 285 Yes 285` Xyle -;,,ii,','S: 1„ 10207, O.s�' :'' 1314 Yes 1314 n-Hexane „_-- 110543 C 3965; .. Yes 3965 224TMP :',.=540841 C 474: . Yes 474 Benzene 71432 A 212 Yes 212 Toluene 108883 C 388 Yes 388 005 Ethylbenzene 100414 C 71 No 71 Xylenes 1330207 C 315 Yes 315 n-Hexane 110543 C 1210 Yes 1210 Benzene ,€..71432 i A, ' 505 Yes 25 Toluene ..`,108883 ,j a , `' 391 ' No 20' 006 Xylem 1330207 £ . 2;. 194•. No 10 ft-Hexane ' 11� " C X927; Yes 196. Ethylbenzene 100.4'14` a'' 27 ! No Y-1.3,- '- ' Benzene 71432 A 4518 Yes 226 Toluene 108883 C 3084 Yes 154 010 Ethylbenzene 100414 C 205 No 10 Xylenes 1330207 C 795 Yes 40 n-Hexane 110543 C 26133 Yes 1307 Benzene 71432 A 250 Yes 12 Toluene 108883 C 208 No 10 011 Ethylbenzene 100414 C 32 No 2 Xylenes 1330207 C 885 Yes 4 n-Hexane 110543 C 1592 Yes 80 Benzene 71432 A 129 No 6 012 n-Hexane 110543 C 836 Yes 42 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput VOC 2.04 0.102 Source 110543 n-Hexane 0.093 0.00465 Source 71432 Benzene 0.014 • 0.0007 Source AIRS ID: 12319A531001-006, 010-012 Page 12 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. Point 002: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput VOC 0.262 0.102 CDPHE 110543 n-Hexane 0.022 0.0011 CDPHE 71432 Benzene 0.007 0.00035 CDPHE Note: The controlled emissions factors for point 002 are based on the flare control efficiency of 95%. Point 003: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 3.9197 14.7000 0.6399 2.4000 CO 1.5465 5.8000 1.2799 4.8000 VOC 0.0107 0.0400 0.0107 0.0400 5000 Formaldehyde 0.021 0.077 0.021 0.077 67561 Methanol 0.0031 0.0115 0.0031 0.0115 75070 Acetaldehyde 0.0028 0.0105 0.0028 0.0105 107028 Acrolein 0.0026 0.0099 0.0026 0.0099 71432 Benzene 0.0016 0.0059 0.0016 0.0059 106990 1,3-Butadiene 0.0007 0.0025 0.0007 0.0025 108883 Toluene 0.0006 0.0021 0.0006 0.0021 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8268 Btu/hp-hr, a . site-rated horsepower value of 80, and a fuel heat value of 918 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Spec Sheet Manufacturer Spec Sheet CO Manufacturer Spec Sheet Manufacturer Spec Sheet VOC Manufacturer Spec Sheet No Control 5000 Formaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas AIRS ID: 123/9A53/001-006, 010-012 Page 13 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division Point 004: Emission Factors-Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.215 AP-42 110543 n-Hexane 0.015 AP-42 71432 Benzene 0.0028 AP-42 108883 Toluene 0.0060 AP-42 100414 Ethylbenzene 0.0011 AP-42 1330207 Xylenes 0.0052 AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L= 12.46*S*P*M/T S =0.6 (Submerged loading: dedicated normal service) P (true vapor pressure)= 5.29 psia M (vapor molecular weight) =68 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 liquids by the VOC emission factor. Point 005: Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 2108 0 208 153 Flanges 102 0 137 72 Open-ended Lines 68 0 14 5 Pump Seals 6 0 0 0 Valves 300 0 53 28 Other 149 0 0 2 VOC Content(wt. 0.2912 N/A 0.9968 1.0000 fraction) Benzene Content(wt" 0.0008 N/A 0.0131 0.0012 fraction) Toluene Content(wt 0.0006 N/A 0.0279 0.0003 fraction) Ethylbenzene(wt 0.0001 N/A 0.0052 0.0001 fraction) Xylenes Content(wt 0.0003 N/A 0.0240 0.0001 fraction) n-hexane Content(wt. 0.0060 N/A 0.0724 0.0001 fraction) '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 AIRS ID: 123/9A53/001-006, 010-012 Page 14 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division Service Connectors 2.0E-04 N/A 2.1E-04 1.1E-04 Flanges 3.9E-04 N/A 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 N/A 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 N/A 2.5E-03 9.8E-05 Other 8.8E-03 N/A 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. Point 006: Emission Factors Emission Factors AIRS -Uncontrolled -Controlled Point CAS# Pollutant Ib/MMscf vented lb/MMscf vented Source VOC 18,034 902 NO, 0.0689 Ib/MMBTU All emission factors CO 0.37 Ib/MMBTU are based on the stated consumption 006 108883 Toluene 37 1.8 and the North Platte 44-11-28HZ gas 1330207 Xylenes 18 0.92 analysis dated 5/25/2012 110543 n-Hexane 373 19 71432 Benzene 48 2.4 The displacement equation can found in "EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3)." Emission factors for CO and NOx found in AP-42 Table 13.5-1 Point 010: Emission Factors Emission Factors AIRS -Uncontrolled -Controlled Point CAS# Pollutant Ib/MMscf vented lb/MMscf vented Source VOC 47830.3 2391.5 NO, 0.068 Ib/MMBTU All emission factors CO 0.37 Ib/MMBTU are based on the stated consumption 010 108883 Toluene 205.4 10.3 and the North Platte 44-11-28HZ gas 1330207 Xylenes 52.9 2.65 analysis dated 5/25/2012 110543 n-Hexane 1737.8 86.9 71432 Benzene 300.5 15.0 AIRS ID: 12319A531001-006, 010-012 Page 15 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division • The controlled emissions factors for point 010 are based on the flare control efficiency of 95%. The displacement equation can found in"EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10-Displacement Equation(10.4-3)? Emission factors for CO and NOx found in AP-42 Table 13.5-1 Point 011: Emission Factors Emission Factors AIRS -Uncontrolled -Controlled Point CAS# Pollutant Ib/MMscf vented Ib/MMscf vented Source VOC 17,957.6 902 NO„ 0.0689 Ib/MMBTU All emission factors CO 0.37 lb/MMBTU are based on the 108883 Toluene 39.6 1 8 stated consumption 011 and the North Platte 44-11-28HZ gas 1330207 Xylenes 16.8 0.92 analysis dated 5/25/2012 110543 n-Hexane 303 19 71432 Benzene 47.5 2.4 The controlled emissions factors for point 011 are based on the flare control efficiency of 95% The displacement equation can found in "EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10-Displacement Equation (10.4-3): Emission factors for CO and NOx found in AP-42 Table 13.5-1 Point 012: Emission Factors Emission Factors AIRS -Uncontrolled -Controlled Point CAS# Pollutant Ib/MMscf vented Ib/MMscf vented Source VOC 18,368.5 902 NO, 0.0689 Ib/MMBTU All emission factors CO 0.37 lb/MMBTU are based on the stated consumption 012 108883 Toluene 42.3 1.8 and the North Platte 44-11-28HZ gas 1330207 Xylenes 18.8 0.92 analysis dated 5/25/2012 110543 n-Hexane 318.6 19 71432 Benzene 49.3 2.4 The displacement equation can found in"EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10-Displacement Equation (10.4-3): Emission factors for CO and NOx found in AP-42 Table 13.5-1 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 ft 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 AIRS ID: 123/9A53/001-006, 010-012 Page 16 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Point 003: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting—effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf 8) Point 003: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting - effective October 19, 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/rice/fr20au10.pdf Additional information regarding area source standards can be found on the EPA website at: htto://www.epa.clov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-Hexane NANSR Synthetic Minor Source of: VOC MACT ZZZZ Area Source Requirements: Applicable MACT HH Area Source Requirements: Not Applicable NSPS KKK Not Applicable NSPS OOOO Not Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60,Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart M—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)OOOOO( AIRS ID: 123/9A53/001-006, 010-012 Page 17 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division 11) 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: htto://www.cdohe.state.co.us/ap/oiloaspermittina.htrnl AIRS ID: 123/9A53/001-006, 010-012 Page 18 of 23 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. AIRS ID: 123/9A53/001-006, 010-012 Page 19 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division 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 applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an altemative 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.gov/cs/Satellite/CDPHE-AP/CBO N/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9A53/001-006, 010-012 Page 20 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean bum engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9A53/001-006, 010-012 Page 21 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition intemal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 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 JJJJ. 2.3.4 Reciprocating intemal combustion engine(RICE) MACT: 40 CFR Part 63, Subpart 7777 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart 7777. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9A53/001-006, 010-012 Page 22 of 23 Colorado Department of Public Health and Environment Air Pollution Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 12319A531001-006, 010-012 Page 23 of 23 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Bonanza Creek Energy Operating Company LLC Permit Number: 12WE2919 Source Name: Antelope P-T-17HZ Tank Battery Source Location: NWNE Sec 17 T5N R62W Equipment Description: Loadout for loading condensate and produced water into trucks, Fugitives AIRS ID: 123/9A53/001,004,005 Review Date: 4/25/2014 Review Engineer Stuart Siffring Section 2—Action Completed X CP2 X Modification APEN Required/Permit Exempt Final Approval Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered"no"to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? 12/23/2013 Section 4—Source Description AIRS Point Equipment Description 001 Ten (10)above ground atmospheric condensate storage tank with a total capacity of 4600 bbls. 004 Truck Condensate Loadout 005 Fugitives Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria x Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes"the provisions of X Yes No Regulation 7,Sections XII and XVII.C may apply) Page 1 Is this source located at an oil and gas exploration site? X Yes No If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate(hydrocarbons that have Yes X No an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Is this source located at a facility that is considered a major source of hazardous air pollutant(HAP) Yes X No emissions? Will this equipment be operated in any NAAQS X Yes No nonattainment area? Does this source load gasoline into transport vehicles? Yes X No Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific emission factors using gas sample and E&P Tanks. AP-42: Chapter 5.2, Equation 1 L= 12.46`S`P`M/T 004 L= loading losses in lb per 1000 gallons loaded S =Saturation Factor P=true vapor pressure of liquid loaded [psia] M=molecular weight of vapors[lb/lb-mole] T=temperature of bulk liquid loaded [deg. RI 005 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 WniellAPT E} AIRS Point Process Consumption/Throughput/Production 001 232,870 BBL per year. 004 254,040 BBL per year condensate loaded Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 2108 972 708 005 Flanges 102 26 30 Open-Ended Lines 68 10 2 Pump Seals 6 0 3 Valves 300 124 80 Other 149 15 30 Bases for Permitted Emissions(Permit IJrrritsl AIRS Point Process Consumption/Throughput/Production 001 232,870 BBL per year. 004 254,040 BBL per year condensate loaded Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 2108 972 708 005 Flanges 102 26 30 Open-Ended Lines 68 10 2 Pump Seals 6 0 3 Valves 300 124 80 Other 149 15 30 Page 2 Does this source use a control device? X Yes, point 001 No Section 6—Emission Summary(tons per year) Point NO, VOC CO Single HAP HAP PTE: 001 258.6 9.9(n-Hexane) 13.0 004 27.4 1.98 (n-hexane) 5.0 005 20.3 0.6 (Hexane) 1.1 Uncontrolled point 001 258.6 9.9(n-Hexane) 13.0 source emission rate: 004 27.4 1.98 (n-hexane) 5.0 005 20.3 0.6 (Hexane) 1.1 Permitted point source 001 0.4 11.9 2.4 0.5(n-hexane) 0.9 emission rate: 004 27.4 1.98 (n-hexane) 5.0 005 20.3 0.6 (Hexane) 1.1 Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Controlled Point Pollutant CAS# BIN Emission Rate Are the emissions Emission Rate (Iblyr) reportable? (lb/yr) Benzene 71432 A 3564 Yes 178 Toluene 108883 C 2162 Yes 108 001 Ethylbenzene 100414 C 134 No 7 Xylenes 1330207 C 535 Yes 27 n-Hexane 110543 C 23722 Yes 1186 Benzene 71432 A 719 Yes N/A n-Hexane 110543 C 3965 Yes N/A 004 Toluene 108883 C 208 No N/A Xylenes 1130207 C 885 Yes N/A Benzene 71432 A 212 Yes N/A Toluene 108883 C 388 Yes N/A 005 Ethylbenzene 100414 C 71 No N/A Xylenes 1330207 C 315 Yes N/A n-Hexane 110543 C 1210 Yes N/A Note: Regulation 3, Part A, Section ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? Page 3 AIRS Point Process Pollutant Regulatory Test Method 001 01 VOC, HAPS PS Memo 05-01 Liquids Analyses according to PS Memo 05-01 Section 9—Source Classification Is this a new previously un-permitted source? Yes X No What is this facility classification? True X Synthetic X Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? X Yes No If"yes"what kind of modification? Minor X Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? For Reg. 3, Part B, III.C.1.a(emissions increase>25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards(NAAQS)? AIRS Point Section 12—Regulatory Review Reoulation:l v Particulate;Smoke.Carbon Monoxide and Sulfur Dioxide Visible emissions shall not exceed twenty percent(20%)opacity during normal operation 001,004,005 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.) Reautatior 2—Odiiz . Section I.A-No person,wherever located, shall cause or allowthe emission of odorous air contaminants from any single source such as to result in detectable odors which are 001,004,005 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. Page 4 Regulation 3-APENs, Construction Permits, Operating Permits, PSD Criteria Pollutants: For criteria pollutants,Air Pollutant Emission Notices are required for: each individual emission point in a nonattainment area with uncontrolled actual emissions of one tons per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is nonattainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) 001,004,005 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 8-hour ozone nonattainment area, but not the 1-hour ozone area. Point 004: The date of interest for determining whether the source is new or modified is therefore November 20, 2007(the date of the 8-hour ozone NA area designation). Operator is using 0.6 saturation factor(submerged fill), therefore, RACT requirements are satisfied. Point 005: Source is using the division standard DI&M plan to comply with RACT, with semi-annual AVO screenings. Regulation 6-New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. 001 Is this source greater than 19,800 gallons (471 bbl)? Yes Is this source subject to NSPS Kb? Some tanks are greater than 471 bbls. WHY? Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS 001 OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks since it is located in an attainment area.) Regulation 8—Hazardous Air Pollutants MACT EEEE: Organic Liquids Distribution 001, Pick one: 004,005 • This source is not subject to MACT EEEE because it is not located at a major source of HAP. MACT HH 001 Pick one: • This source is not subject to MACT HH because it is not located at a major source of HAP. Section 13—Aerometric Information Retrieval System Coding Information Process/ Pollutant Process Emission Fugitive Emission Factor Control Point Process Description throughput Factor (Y/N) Source (%) Limit CAS# 48.57 CDPHE PS Memo lb/1000 V0C No 05-01 NA gal (converted to lb/1000 throughput gal) E&P 0.333 CDPHE PS Memo Condensate 232,870 lb/1000 Benzene 05-01 01 Storage BBI/yr gal /71432 N° (converted to lb/1000 NA 001 Tanks throughput gal) 2.21 CDPHE PS Memo lb/1000 Hexane/ No 05-01 NA gal 110543 (converted to lb/1000 throughput gal) SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses Page 5 5.13 lb/1,000 V0C No AP-42 0 gallon throughput 254,040 0.0674 Truck Condensate lb/1,000 01 Loadout BSL/yr gallon Benzene No AP-42 0 004 throughput 0.3716 lb/1,000 n-Hexane No AP-42 0 gallon throughput SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 01 Fugitive V0C _ _ VOC Yes EPA-453/R-95- 0 005 Leak Emissions 017,Table 2-4 SCC 31000220: All Equip. Leak Fugitives(Valves,flanges,connections,seals,drains) Section 14—Miscellaneous Application Notes AIRS Point 001 Condensate Tanks Site specific emission factors were used by source. Liquids analysis was properly entered in the E&P Tanks modeling run. AIRS Point 004 Truck Condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service based on source's description/drawings P 5.29 Psia AP-42 Figure 7.1-13a M 68 Lb/lb-mole E&P Tanks T 524 Deg R Based on source's knowledge of bulk liquid temperature L 5.13 Lb/10A3 gal 0.215 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] L 5.13lb/10'13 gal 0.2151b/bbl Annual requested Throughput 254,040bbl/yr Annual requested VOC emissions 54735.51b/yr 27.4tpy Page 6 Division Information Engineer: Stuart Siffring Control Engineer: Stef Rucker Review Date: 12/23/2013 Application Date: 04/28/2014 Facility Identifiers Permit No. 12WE2919 Potentially Located within EAC-determine attainment status of NOx and County# 123 Weld Attainment Status AIRs Facility# 9A53 PM10 Attainment Point# 012 PM2.5 Attainment Facility Equipment ID FL-1 SOx Attainment NOx Nonattainment VOC Nonattainment CO Attainment Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Antelope P-T-17HZ Tank Battery NWNE Sec 17 T5N R62W Source Location: SIC: 1311 Elevation(feet) 4694 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address City,State Zip: Denver,CO Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pyoung@bonanzacrk.com Section 02: Requested Action X New permit/newly reported emission source Request Mod-Change fuel/equipment Request Mod-Change permit limit Request Mod-Change company name Request Mod-Transfer of ownership Request Mod-Other 'Request to limit HAPs with federally enforceable limits Issuance Number: 2 Add'I Info and notes: New point at existing facility Section 03: General Facility Information For existing sources,operation began on: 12/23/2013 For New/recon sources,projected startup date: Normal hours of operation: _ 24 hrs/day 7 days/wk 10 weeks/yr General description of equipment purpose: Emergency Flare Will this equipment be operated in any nonattainment area?' Yes Section 04: Flare Information Manufacturer: Candlestick Flare Model Number: TBD Flare Serial Number: To Be Determined Information Flare capacity 14.8 mmbtu/hr Max. natural gas 18083.3 scf/hour used consumption §action 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=C1*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm O 18083.3 scf/hr MW 23.5 Ib/Ib-mol Hors of op. 240 lws/yr Requested Throughput 2.6 MMscf/yr Component mole% MW mass fraction Component lb/hr Ib/yr tpy propane 2.288 44.09 0.0426 propane 47.711 11450.722 5.725 isobutane 0.8213 58.12 0.0203 isobutane 22.775 5466.095 2.733 n-butane 2.5616 58.12 0.0634 n-butane 71.035 17048.518 8.524 isopentane 0.484 72.15 0.0149 isopentane 16.662 3998.816 1.999 n-pentane 0.6303 72.15 0.0194 n-pentane 21.698 5207.549 2.604 n-hexane 0.1401 86.18 0.0051 n-hexane 5.761 1382.593 0.691 cyclohexane 0.0353 84.18 0.0013 cyclohexane 1.418 340.278 0.170 Other hexane 0.2297 86.18 0.0084 Other hexanes 9.445 2266.821 1.133 heptanes 0.1165 100.21 0.0050 heptanes 5.570 1336.862 0.668 methylcycloh 0.0282 98.19 0.0012 methylcyclohe 1.321 317.078 0.159 224-TMP 0.0001 114.22 0.0000 224-TMP 0.005 1.308 0.001 Benzene 0.0239 78.11 0.0008 Benzene 0.891 213.774 0.107 Toluene 0.0174 92.14 0.0007 Toluene 0.765 183.589 0.092 Ethylbenzene 0.0024 106.17 0.0001 Ethylbenzene 0.122 29.178 0.015 Xylenes 0.0067 106.17 0.0003 Xylenes 0.339 81.457 0.041 C8+Heavies 0.0785 315 0.0105 C8+Heavies 11.798 2831.587 1.416 Mass Fraction VOC: 0.1938 Total 26.078 Total 26.078 tpy VOC 24.11 1.2055 Notes Mole%,MW,and mass fractions from extended gas analysis from Antelope P-T-17H2 gas analysis dated 3/11/2013 Scenario A CASA Total(Ib/yr) Bin Reportable? n-hexane 110543 1382.6 C Yes 224-TMP 540841 1.3 C No Benzene ' 71432 213.8 A Yes Toluene 108883 183.6 C No E-Benzene 100414 29.2 C No Xylenes 1330207 81.5 C No Resultant Emission Factors VOC 12017.585 lb/MMscf natural gas used 18368.5 Benzene 49.257 Ib/MMscf natural gas used 128.0674248 n-hexane 318.570 Ib/MMscf natural gas used Toluene 42.302 Ib/MMscf natural gas used E-eenzene 6.723 Ib/MMscf natural gas used Xylenes 18.769 lb/MMscf natural gas used 224-TMP 0.301 lb/MMscf natural gas used • Division Information Engineer: Stuart Siffring Control Engineer: Stet Rucker' Review Date: 12/23/2013 Application Date: 04/28/2014 Facility Identifiers Permit No. 12WE2919 Potentially Located within EAC-determine attainment status of NOx and' County ft 123 Weld Attainment Status AIRs Facility*/ 9A53 PM10 ' Attainment Point*/ 011 PM2.5 Attainment Facility Equipment ID P-3 SOx Attainment NOx Nonattainment VOC Nonattainment CO Attainment Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Antelope P-T-17HZ Tank Battery NWNE Sec 17 T5N R62W Source Location: SIC: 1311 Elevation(feet) 4694 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address City,State Zip: Denver,CO Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pvouno(olbonanzacrk.com Section 02: Requested Action X New permit/newly reported emission source Request Mod-Change fuel/equipment Request Mod-Change permit limit Request Mod-Change company name Request Mod-Transfer of ownership Request Mod-Other 'Request to limit HAPs with federally enforceable limits Issuance Number: 2 Add'I Info and notes: New point at existing facility Section 03: General Facility Information For existing sources,operation began on: 12/23/2013 For New/recon sources,projected startup date: Normal hours of operation: 24 hrs/day 7 days/wk 10 weeks/yr General description of equipment purpose: Pump used for water transfer Will this equipment be operated in any nonattainment area?' Yes Section 04: Pump Information Manufacturer: Sandpiper Model Number: G1F Pump Serial Number: To Be Determined Information Pump capacity 9.1 gallons per minute pumped Max.pump natural 500 scf/hour used gas consumption Section 05: Emission Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q•MW•Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Q 600 scf/hr MW 23.4 Ib/Ib-mol Hours of Op. 8760 hotrs/yr Requested Throughput 5.3 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr-- - tpy propane 7.6279 44.09 0.1437 propane 5.324 46640.289 23.320 isobutane 0.7298 58.12 0.0181 isobutane 0.671 5882.279 2.941 n-butane 2.1807 58.12 0.0542 n-butane 2.006 17576.714 8.788 isopentane 0.3816 72.15 0.0118 isopentane 0.436 3818.219 1.909 n-pentane 0.4908 72.15 0.0151 n-pentane 0.561 4910.854 2.455 n-hexane 0.1052 86.18 0.0039 n-hexane 0.144 1257.298 0.629 cyclohexane 0.0353 84.18 0.0013 cyclohexane 0.047 412.097 0.206 Other hexane 0.176 86.18 0.0065 Other hexanes 0.240 2103.465 1.052 heptanes 0.0839 100.21 0.0036 heptanes 0.133 1165.975 0.583 methylcycloh 0.0202 98.19 0.0008 methylcyclohe 0.031 275.065 0.138 224-IMP 0.0001 114.22 0.0000 224-TMP 0.000 1.584 0.001 Benzene 0.0195 78.11 0.0007 Benzene 0.024 211.231 0.106 Toluene 0.0118 92.14 0.0005 Toluene 0.017 150.781 0.075 Ethylbenzene 0.0011 106.17 0.0000 Ethylbenzene 0.002 16.196 0.008 Xylenes 0.0032 106.17 0.0001 Xylenes 0.005 47.116 0.024 C8+Heavies 0.0524 315 0.0071 C8+Heavies 0.261 2289.064 1.145 Mass Fraction VOC: 0.2673 Total 43.379 Total 43.379 tpy VOC uncontrolled 47.19 controlled 2.36 Noes Mole%,MW,and mass fractions from a:dended gas analysis from Antelope P-T-17HZ gas analysis dated 3/11/2013 Scenario A CAS# Total(Ib/yr) Bin Reportable? n-hexane 110543 1257.3 C Yes 224-TMP 540841 1.6 C • No Benzene 71432 211.2 A Yes 250.000 12.500 Toluene 108883 150.8 C No E-Benzene 100414 16.2 C No Xylenes 1330207 47.1 C No Resultant Emission Factors VOC 16506.512 lb/MMscf natural gas used 17957.63 Benzene 40.189 Ib/MMscf natural gas used 47.48 n-hexane 239.212 lb/MMscf natural gas used Toluene 28.687 lb/MMscf natural gas used E-Benzene 3.081 lb/MMscf natural gas used Xylenes 8.964 lb/MMscf natural gas used 224-TMP 0.301 lb/MMscf natural gas used Division Information Engineer: Stuart Siffrng Control Engineer: Stef Rucker Review Date: 12/23/2013 Application Date: 04/28/2014 Facility Identifiers Permit No. 12WE2919 Potentially Located within EAC-determine attainment status of NOx and' County ft 123 Weld - Attainment Status AIRs Facility# 9A53 PM10 Attainment Point# 010 PM2.5 Attainment Facility Equipment ID Sep-2,Sep-3 SOx Attainment NOx Nonattainment VOC Nonattainment CO Attainment Section 01: Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Antelope P-T-17HZ Tank Battery Source Location: NWNE Sec 17 T5N R62W SIC: 1311 Elevation (feet) 4694 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address City,State Zip: Denver,CO Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pvouno(aulbonanzacrk.com Section 02: Requested Action X New permit/newly reported emission source Request Mod-Change fuel/equipment Request Mod-Change permit limit Request Mod-Change company name Request Mod-Transfer of ownership Request Mod-Other Request to limit HAPs with federally enforceable limits Issuance Number: 2 Add'l Info and notes: new point at existing facility Section 03: General Facility Information For existing sources,operation began on: 12/23/2013 For New/recon sources,projected startup date: Normal hours of operation: 24 hrs/day 7 days/wk 10 weeks/yr General description of equipment purpose: Wellhead separators Will this equipment be operated in any nonattainment area?' Yes Section 04: Point Information Manufacturer: Separator Model Number: TBD Serial Number: To Be Determined Separator . Information Separator capacity 3.22 mmbtu/hr Max. natural gas 1717 scf/hour used consumption Section 05: Emission Calculations Eminion Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mot)at 60F and 1 atm Q 1717 sd/hr VOC wt% 54.8 71985287.52 lbs MW 33.1 Ib/Ib-mol Control Eff. 0.95 35992.64376 Hours of Op. 8760 hmvsyr Requested Throughput 15 MMscf/yr Emission Factor 47859.63061 Ibimmsd Uncontrolled emissions 358.9472296 Controlled 17.94736148 Component mole% MW mass fraction Component Ib/hr lb/yr tpy propane o 44.09 0.0000 propane 0.000 - 0.000 0.000 isobutane 0 58.12 0.0000 isobutane 0.000 0.000 0.000 n-butane o 58.12 0.0000 n-butane 0.000 0.000 0.000 isopentane 0 72.15 0.0000 isopentane 0.000 0.000 0.000 n-pentane o 72.15 0.0000 n-pentane 0.000 0.000 0.000 n-hexane 1.9908 86.18 0.0518 n-hexane 7.773 68087.802 34.044 cyclohexane o 84.18 0.0000 cyclohexane 0.000 0.000 0.000 Other hexane o 86.18 0.0000 Other hexanes 0.000 0.000 0.000 heptanes o 100.21 0.0000 heptanes 0.000 0.000 0.000 methylcycloh 0 98.19 0.0000 methylcyclohe 0.000 0.000 0.000 224-TMP 0.0922 114.22 0.0032 224-TMP 0.477 4179.345 2.090 Benzene 0.3442 78.11 0.0081 Benzene 1.218 10669.712 5.335 Toluene 0.235 92.14 0.0065 Toluene 0.981 8593.128 4.297 Ethylbenzene 0.0156 106.17 0.0005 Ethylbenzene 0.075 657.297 0.329 Xylenes 0.0606 106.17 0.0019 Xylenes 0.291 2553.346 1.277 C8+Heavies o 315 0.0000 C8+Heavies 0.000 0.000 0.000 Mass Fraction VOC: 0.0721 Total 47.370 Total 47.370 tpy VOC 24.11 1.2055 Notes Mole%,MW,and mass fractions from extended gas analysis from Antelope P-T-17HE gas analysis dated 3/11/2013. VOC wt%is averaged from many sites,and is higher than the samples used for other points at this feebly. This big lead to a conservative estimate of emissions. Scenario A CASS Total(Ib/yr) Bin Reportable? n-hexane 110543 67902.6 C Yes 224-TMP 540841 4168.0 C Yes Benzene 71432 10640.7 A Yes Toluene 108883 8569.7 C Yes E-Benzene 100414 655.5 C Yes Xylenes 1330207 2546.4 C Yes Resultant Emission Factors VOC 47859.631 lb/MMscf natural gas used n-hexane 4526.838 Ib/MMscf natural gas used 224-TMP 277.865 lb/MMscf natural gas used Benzene 709.379 lb/MMscf natural gas used Toluene 571.317 lb/MMscf natural gas used E-Benzene 43.701 Ib/MMscf natural gas used Xylenes 169.760 lb/MMscf natural gas used Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OH AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) AIRS ID#': 123-9A53-001 ❑ APEN update only° ® New or previously unreported battery ® Modification to existing source ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GP0I ❑ Synthetic minor facility &cancellation request for individual permit6: I E] Located in the 8-hr Ozone Control Area' 0 Application for or Modification of an individual permit O Registered under general permit no.GPO I ❑ Administrative permit amendment' O Permitted under individual permit: 0 Other.Annly for coverage under permit#12WE2919 For individual permit applications,check if you wants: 0 A copy of the preliminary analysis conducted by the Division 0 To review a draft of the permit prior to issuance Company Name9: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 Mailing Address°: 410 171h Street,Suite 1500 City: Denver State: CO Zip: 80202 E-mail: pyousg@gommsa com Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 - • 4-400bbl Tank Battery Name': Antelope P-17 Production Facility(COGCC#428964) Number of tanks: 6-500bb1 Locations(QQ Sec.Twp.Range.): NW/NE Sec 17,T5N,R62W County: Weld Total tank capacity[bbl]: 4600 4-2012 Calendar year for which"Actual"data applies13: 2013 Year(s)tank(s)were placed in service': 6-2013 One(I)Cimarron Energy 60"ECD SN:5601709 Control Control Description":. Five(5)Leed Fabridation L30-0010 SN:21297,21296,20924,21295,21294 Efficiency16: 95% Condensate Throughput"[bbl/year] Requested]°: 232,870 Maximum for PTE calculation'9: 232,870 Actual20: 211,700 While Controls Operational" 211,700 -Other equipment at facility': Heater treaters,produced water tanks,natural gas-fired engines,pneumatic pumps Comments: Estimated emissions at throughputs listed above. Use NM for requested throughput/emission values unless requesting art individual permit O Check if the Division is to calculate emissions. 0 Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emissions° Actual Emissions° Pollutant34 [lb/bbl] PTE" Uncontrolled" Controlled" Uncontrolled" Controlled" VOC[tons/year] 2.04 258.58 258.58 11.85 215.49 10.77 NOx[tons/year] N/A 118.67 0.43 CO[tons/year] N/A N/A 645.70 2.36 Benzene[lbs/year] 0.014 3,564.0 3,564.0 163.4 2,970.0 148.5 n-Hexane[lbs/year] 0.093 23,721.6 23,721.6 1,087.2 19,768.0 988.4 Wells serviced by this tank or tank batte API#: 05-123-35600 Name: Antelope P-T-17HZ ./— --.. ❑Newly Reported Well API#: 05-123-37653 Name: Antelope K-O-17HNB / /�''V"i'\ ®Newly Reported Well API#: 05-123-37651 Name: Antelope U-Y-17I-INB I I -CC. �-� _ 7(;\'• \ ®Newly Reported Well API#: Name: / / ❑Newly Reported Well API#: Name \ -..„:'" / O Newly Reported Well API#: Name: \ / ❑Newly Reported Well API#: Name: - O Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a o for coverage under general permit GP01,I further certify that this source is and will be operated in full c ance wi eac condr� permit GP0I. / 2 Signature of Legally Au rizedrPerson(not a vendor or consultant) Date David J.Lillo Vice President,Rocky Mountain Assets Mgmt 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 call: --- - filing of up to 5 tank battery APENS. 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