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Home My WebLink About20143731.tiff 4 CAE COLORADO CO tt Department of Public Health Fr Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County -Clerk to the Board 1150 O St PO Box 758 Greeley. CO 80632 November 20, 2014 Dear Sir or Madam: On November 26, 2014, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC—North Platte P-T-34HZ Production Facility. 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 beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health& Environment APCD-SS-B I 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards. t D7A-CC,C-4 Clara Gonzales Public Notice Coordinator Stationary Sources Program RECEIVED Air Pollution Control Division Enclosure Clr 2��4 1 ntRITY COMMIS __ S /A' a: f 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickentooper, Governor ! Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer el ?late Rt& 12-8- i L ?t.J � 2014-3731 CC tf SZ CDPH Etint Air Pollution Control Division CO i Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company LLC—North Platte P-T-34HZ Production Facility—Weld County Notice Period Begins: November 26.2014 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: North Platte P-T-34HZ Production Facility Oil and gas exploration and production facility 6.3 miles east of Kersey, Colorado 80644 (SESE. Section 27,T5N, R63 W) Weld County The proposed project or activity is as follows: operator requests a permit to operate four produced water tanks, a truck loadout for condensate,two pneumatic pumps, two separators, an emergency flare, and fugitive emissions 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.I.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis. and a draft of Construction Permit 13WE 1363 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: Kirk Bear Colorado Department of Public Health and Environment 4300.Cherry Creek Drive South, APCD-SS-BI Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us WVCOLORADO t I 1..,,,._,= STATE OF COLORADO Op COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT � AIR POLLUTION CONTROL DIVISION • �„ TELEPHONE: (303) 692-3150 �, 41816 CONSTRUCTION PERMIT PERMIT NO: 13WE1363 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 exploration and production facility known as the North Platte P-T-34HZ Production Facility, located in the SESE, Section 27, T5N, R63W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Two above ground 300 bbl tanks and two 60 bbl concrete vaults PW Tanks 008 used for produced water storage. The 300 bbl tanks are controlled by an enclosed flare. The 60 bbl vaults are uncontrolled. TL 009 Truck Condensate Loadout FUG 010 Fugitive equipment leaks P-1 & P-2 011 Two 600 scf/hr pneumatic pump used for water transfer& heat trace Sep-1 & 012 Two separators controlled by 4 enclosed flares. Flares have a minimum combustion efficiency of 95%. The flares are enclosed. Sep-2 u FL-1 013 Flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Point 011: 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 seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to AIRS ID: 123-9394 Page 1 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division the Division. The Notice of Startup form may be downloaded online at www.cdphe.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, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, I I I.F.4.) 4. Within one hundred and eighty days (180) after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas vented from each low pressure separator. The operator shall use the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed one hundred and eighty(180) days after issuance of this permit. 5. 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.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of sell-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 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO PW Tanks 008 0.5 Point TL 009 14.4 Point FUG 010 14.6 Fugitive P-1 &P-2 011 0.5 4.0 2.6 Point Sep-1 &Sep-2 012 0.4 7.2 2.1 Point AIRS ID: 123-9394 Page 2 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division FL-1 013 0.5 2.0 2.8 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. 8. Point 010: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility 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. 9. 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 PW Tanks 008 Enclosed Flares VOC P-1 &P-2 011 Enclosed Flares VOC Sep-1 & 012 Enclosed Flares VOC Sep-2 FL-1 013 Open Flare VOC PROCESS LIMITATIONS AND RECORDS 10. 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 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 Limit Equipment ID Point PW Tanks 008 Produced Water Throughput 78840 bbl TL 009 Oil Loaded 144540 bbl P-1 & P-2 011 Natural Gas 10.5 MMscf AIRS ID: 123-9394 Page 3 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division Sep-1 &Sep-2 012 Gas vented to enclosed flares from separator 6.0 MMscf FL-1 013 Gas vented from separator 5.8 MMscf 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. 11. Upon installation of the flow meter required under Condition 4, the owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from each low pressure separator using a flow meter. The flow meter shall continuously measure flow rate and record total volumetric flow vented from each separator. The owner or operator shall use monthly throughput records to demonstrate compliance with the limits specified in Condition 10 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 12. 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) 13. 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.) 14. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 15. Point 008: The storage tanks covered by this permit are subject to the emission control requirements in Regulation No. 7, Section XVII.C.1. The owner/operator must install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. The source shall follow the inspection requirements of Regulation No. 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control must be achieved according to the following schedule: o If constructed on/after May 1, 2014, within 90 days of the date that the storage tank commences operation; o If constructed before May 1, 2014, by May 1, 2015. 16. Point 009: 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) 17. Point 009: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): AIRS ID: 123-9394 Page 4 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with Condition 17 (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 18. Point 009: All hydrocarbon liquid loading 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. 19. Point 010: 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. 20. Point 010: 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 for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). Directed Inspection & Maintenance (DI&M), as required by Conditions No. 21 shall satisfy the requirement to apply Reasonably Available Control Technology (RACT). 21. Point 010: 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. i. Auditory/visual/olfactory inspection (AVO) will be performed on a semi-annual basis. The first annual inspection shall occur within 180 days of permit issuance. H. For each leak found in the AVO inspection, a gas detector may 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. Component leaks less than 10,000 ppm shall not require repair. 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. AIRS ID: 123-9394 Page 5 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division 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 using AVO 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 inspections, 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. 22. Point 010: The owner or operator shall follow the Directed Inspection and Maintenance (DI&M) program and record keeping format as approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your DI&M plan are subject to Division approval. 23. Point 013: The open flare covered by this permit has been approved as an alternative emissions control device under Regulation No. 7, Section XVII.B.2.e. The open flare shall have no visible emissions during normal operations and be designed so that an observer can, by means of visual observation from the outside of the open flare, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. This flare must be equipped with an operational auto-igniter according to the following schedule: o If installed on/after May 1, 2014, upon installation of the combustion device; o If installed before May 1, 2014, by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. OPERATING & MAINTENANCE REQUIREMENTS 24. 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.) 25. Point 008: a. VCUs shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed VCU, or by other convenient means approved by the Division, determine whether the VCU is operating properly. AIRS ID: 123-9394 Page 6 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a VCU include, but are not limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its resolution, the date range the control was inoperable, and the produced water production through the battery during the downtime. During control device downtime, emissions shall be considered to be uncontrolled. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 26. Point 010: 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. 27. Point 013: Within one hundred and eighty days (180) after issuance of this permit, the owner or operator shall demonstrate compliance with opacity standards, using EPA Method 9 to measure opacity from the flare. (Reference: Regulation No. 1, Section II.A.1 &4) Periodic Testing Requirements AIRS ID: 123-9394 Page 7 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division 28. Point 010: 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 analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATE OPERATING SCENARIOS 29. Point 011: This pump 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. 30. Point 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. 31. Point 011: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 32. All previous versions of this permit are cancelled upon issuance of this permit. 33. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th 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 (NO,J in ozone nonattainment areas emitting less than 100 tons of VOC or NO■ per 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 AIRS ID: 123-9394 Page 8 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 34. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 35. 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. 36. 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. 37. 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. 38. 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. 39. 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 AIRS ID: 123-9394 Page 9 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division 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 of a source may request a hearing before the AQCC for review of the Division's action. 40. 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. 41. 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: Kirk Bear Permit Engineer Permit History Issuance Date Description Issuance 2 This Issuance Issued to Bonanza Creek Energy Operating Company LLC AIRS ID: 123-9394 Page 10 of 15 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.colorado.gov/cs/Satellite?c=Document C&childpadename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pauename=CBONWrapper 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 Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (lb/yr) reportable? (Ib/yr) 008 Benzene 71432 552 Yes 28 008 n-Hexane 110543 1734 Yes 87 009 Benzene 71432 361 Yes 361 009 n-Hexane 110543 2155 Yes 215 • 009 Toluene 108883 837 Yes 837 009 Ethylbenzene 100414 114 No 114 009 Xylenes 1330207 700 Yes 700 010 Benzene 71432 140 No 140 010 n-Hexane 110543 862 Yes 862 010 Toluene 108883 282 Yes 282 010 Ethylbenzene 100414 43 No 43 010 Xylenes 1330207 232 No 232 011 Benzene 71432 212 No 11 011 n-Hexane 110543 2000 Yes 100 011 Toluene 108883 132 No 7 011 Ethylbenzene 100414 12 No 0 AIRS ID: 123-9394 Page 11 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division 011 Xylenes 1330207 52 No 3 012 Benzene 71432 1519 Yes 76 012 n-Hexane 110543 9198 Yes 460 012 Toluene 108883 1224 Yes 61 012 Ethylbenzene 100414 129 No 6 012 Xylenes 1330207 437 Yes 22 013 n-Hexane 110543 1371.6 Yes 68.6 5) The emission levels contained in this permit are based on the following emission factors: Point 008: Uncontrolled Emission Pollutant Factors Source lb/bbl Produced Water VOC 0.262 CDPHE n-Hexane 0.022 CDPHE Benzene 0.007 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 009: Uncontrolled Emission Factors Pollutant Ib/bblloaded Source VOC 0.1997 AP-42 Benzene 0.0025 AP-42 n-Hexane 0.0149 AP-42 Toluene 0.0058 AP-42 Xylenes 0.0049 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) =4.9 psia M (vapor molecular weight) =68 IbAb-mol T(temperature of liquid loaded)= 524°R Point 010: Component Gas Heavy Oil Light Oil Water/Oil Connectors 1762 0 676 534 Flanges 98 0 16 20 Open-ended Lines 54 0 6 2 Pump Seals 8 0 0 2 Valves 246 0 90 58 Other 124 0 14 20 AIRS ID: 123-9394 Page 12 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division VOC Content (wt.fraction) 0.2528 0.3 0.9964 1 Benzene Content(wt. fraction) 0.0003 0.001 0.0125 0.0012 Toluene Content (wt. fraction) 0.0002 0.001 0.029 0.0003 Ethylbenzene (wt. fraction) 0.0001 0.001 0.004 0.0001 Xylenes Content (wt. fraction) 0.0001 0.02 0.0243 0.0001 n-hexane Content(wt. fraction) 0.0032 0.001 0.0747 0.0001 *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 W Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R-95-017 Table 2-4 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 analyses. Point 011: Uncontrolled Emission Factors Pollutant lb/MMscf vented Source NOx(lb/MMBtu) 0.068 AP-42 CO (lb/MMBtu) 0.37 AP-42 VOC 15056.2 Gas Analysis Benzene 20.3 Gas Analysis n-Hexane 190.4 Gas Analysis Toluene 12.7 Gas Analysis Xylenes 4.9 Gas Analysis Point 012: Uncontrolled Pollutant Emission Factors Source lb/MMscf NOx (lb/MMBtu) 0.068 AP-42 CO (lb/MMBtu) 0.37 AP-42 VOC 47854.1 Gas Analysis Benzene 125.5 Gas Analysis Toluene 101.1 Gas Analysis Ethylbenzene 10.6 Gas Analysis Xylenes 36.1 Gas Analysis n-hexane 760.1 Gas Analysis AIRS ID: 123-9394 Page 13 of 16 Colorado Department of Public Health and Environment Air Pollution Control Division Point 013: Uncontrolled Pollutant Emission Factors Source Ib/MMscf NOx(Ib/MMBtu) 0.068 AP-42 CO(lb/MMBtu) 0.37 AP-42 VOC 13782.8 Gas Analysis Benzene 23.3 Gas Analysis Toluene 16.3 Gas Analysis Ethylbenzene 1.7 Gas Analysis Xylenes 6.2 Gas Analysis n-hexane 163.7 Gas Analysis 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice(APEN)associated with this permit is valid for a term of five years from the date it was received by the Division.A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of:VOC NANSR 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: htto://ecfr.aooaccess.aov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60,Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart 7777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX AIRS ID: 123-9394 Page 14 of 15 Colorado Department of Public Health and Environment Air Pollution Control Division 9) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification • AIRS ID: 123-9394 Page 15 of 15 • Division Information • Engineer: Kirk Bear • Control Engineer: Chris Laplante Review Date: 10/23/2014 Application Date: 11/19/2013 Facility Identifiers Permit No. 13WE1363 AIRS County# 123 Weld Facility# 9394 Facility Type: exploration and production facility ID Located in the 8-hour non-attainment area? O True Minor ®Synthetic Minor for: r VOC r NOx r CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: North Platte Section 34 Source Location: SESE, Section 27,T5N, R63W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address /,State Zip: Denver,CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pvoung@bonanzacrk.com 'Requested Action Self Certification Required? Yes Issuance Number: 2 Source Description: Oil and gas exploration and production facility known as the North Platte Section 34, located in the SESE, Section 27, T5N, R63W,Weld County. Colorado. Point Name Type Control Action 008 PW Tanks Water Tanks Flare Cancel GP05 Coverage Change Permit 009 TL Loadout None Limit 010 FUG Fugitives None Change Permit Limit 011 P-1 Pump Flare New Point 012 Sep-1 & Separator Venting Flare New Point Sep-2 013 FL-1 Separator Venting Flare New Point Two above ground 300 bbl tanks and two 600 bbl concrete vaults used for produced water storage. The 300 bbl tanks are controlled by an enclosed flare. The 60 bbl vaults are 008 uncontrolled. Emissions Calculations Requsted Throughput 78840 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 10.3 tpy 0.5 tpy CDPHE Benzene 0.007 lb/bbl 552 lb/yr 28 lb/yr CDPHE n-Hexane 0.022 lb/bbl 1734 lb/yr 87 lb/yr CDPHE Regulatory Review 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 IIA.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. Reouletion 2-Odor . Section I.A-No person,wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 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. 009 Truck Condensate Loadout Calculations L= 12.46*S*P*M/T(AP-42: Chapter 5.2, Equation 1) L= loading losses in lb per 1000 gallons loaded Factor Meaning _Value Units Source S Saturation Factor _ 0.6 AP-42 P True Vapor Pressure 4.9 psia Sales Oil Analysis M Molecular Weight of Var 68 lb/lb-mole AP-42 T Liquid Temperature 524 deg. R Field Data L 4.75 lb/1000 gal 0.20 lb/bbl Annual requested Throughput 144540 bbl/yr 6070680 gal/yr Annual requested VOC emissions 28859 lb/yr 14.43 tpy Control: None Efficiency: 0.00% NCRPs Component Mass Fraction Benzene 0.0125 n-hexane 0.0747 Toluene 0.0290 Xylenes 0.0243 Source: Condensate Analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.1997 lb/bbl 14.4 tpy 14.4 tpy AP-42 Benzene 0.0025 lb/bbl 361 lb/yr 361 lb/yr AP-42 n-Hexane 0.0149 lb/bbl 2156 lb/yr 2156 lb/yr AP-42 Toluene 0.0058 lb/bbl 837 lb/yr 837 lb/yr AP-42 Xylenes 0.0048 lb/bbl 701 lb/yr 701 lb/yr AP-42 010 Fugitive pWpmes leaks Repletion 7 titesaatlnn Operating toss: 8760 hours/year Emission Fedor Source EPA-453/R-05-017 Table N - Canto,Efficiency Source: None Calculations Emission Fact pally- ENsslcss Santos Component Type Count scan Control(%)Pasulmt Pass Faction pm Table 24 Table 24 Res Connectors 1782 2.00E-00 1.00EM 0.0% VOC 02528 61161726 Flanges 98 3.90E-00 5.71E-0fi 0.0% Benzene - 0.0003 0.0078615 Open-Ended Lines 54 2.00E-03 1.50E-05 0.0% Toluene 0.0002 0.0052343 Gas Pump Seen 8 2.10E-03 350E-06 0.0% Etthtenzene 0.0001 0.0028172 Vales 248 050E-03 250E-05 0.0% )('arena 0.0001 0.0026172 Other 124 8.80E-03 120E-00 0.0% Mlave 0.0032 0.06374 Connectors 750E-05 750E-05 0.0% VOC 0.3 Flanges 3.90E-07 350E-0T 0.0% Benzene 0.001 HeaWOW 0pen3:rvd lines 1.00E-0e 7.20E-0fi 0.0% Toluene 0.001 Pump Seen 0.001+00 0.00E00 0.0% EBNaansana 0.001 VaNes 8.40E-06 8.40E-06 0.0% )pleea 0.02 Other 3.20E-05 3.20E-05 0.0% Move 0.001 Conmpors 678 2.10E-06 7.50E-06 0.0% VOC 0.9964 0.8289838 Flanges 18 1.10E-06 2.40E-05 0.0% Benzene 0.0125 0.058071 light oil Open-Ended lines 6 1.00E-03 1.40E-05 0.0% Toluene ' 0.029 0.1347255 Pump Seals 0 130E-02 5.10E-00 0.0% E8018enzane 0.004 0.0186826 Valves 90 2.50E-03 1.90EM 0.0% %pones 0.0243 0.1128907 Other 14 7.50E-03 1.10E-01 0.0% M1eve 0.0747 0.3470344 Connectors 534 1.10E-01 1.00E-05 0.0% VOC 1 3.3247091 Flanges 20 2.90E-06 2.90E-06 0.0% Benzene 0.0012 0.0039897 Wei - Open-Ended Lines 2 250E-0e 3.50E-06 0.0% Toluene 0.0003 0.0009974 Pump Seen 2 2.10E-05 2.40E-05 0.0% Ellphonzene 0.0001 0.0003325 Valves 58 9.80E-05 9.70E-06 0.0% )(Worms 0.0001 0.0003325 Other 20 1.40E-02 5.90E-05 0.0% Move 00001 0.0003325 Em aeons Summary Table PatulaM Uncontrolled Emhsbns Controlled Emissions Source VOC 14.6 WV 14.6 toe AP/AS-VR-95-017 Table 2-4 Benzene 140 INM 140 lb/vr EPA453/R-95-017 Table 2-4 Torten 282 IbM 282 EPA-453/R-95-017 Table 24 901v me 43 IbM 43 4y7 EPA 53/R-95017 Table 24 %Ilenas 232 lbw 232 be. EPA-453/R-95-017 Tags 2-1 Mb1e 882 IoM B82 byr EPA-4538A95-017 Table 24 Regulatory Applicability Reg.3 (Operator has agreed on the OlMslan's standard conditions for RACT. F 011 Two 600 scf/hr pneumatic pump used for water transfer 8 heal trace Pump Information Manufactur Sandpiper Model Number:GIF sepal Pump Number:1902031 81981471 Information Pump capacity 182 gallons per minute pumped natural gas 1200 scf/hour used consumptio Control Flare 9500%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(109-3) Ex=Q•MW aXx/C Ex=emissions of pollutant a 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 a molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Q 1200 scf/hr MW 22 s Ib/Ib-mot Hours of OP 8760 hemsyr Requested Throughput 10.512 MMscf/yr Component mole 56 MW mass fraction Component lb/hr lb/yr my CO2 211 44 0.0411 CO2 2.940 25750.240 12.875 nitrogen 045 28 0.0061 nitrogen 0.434 3805.399 1.903 methane 70.3515e 16.04 0.4993 methane 35.729 312983.379 156.492 ethane 14366 30.07 0.1911 ethane 13.678 119816.170 59908 propane a 0658 44.09 0.1574 propane 11.260 98635.600 49.318 isobutane 08441 58.12 0.0217 isobutane 1.553 13607.102 6.804 i n-butane 2353 58.12 0.0605 n-butane 4.330 37930.946 18.965 isopentane 04248 72.15 0.0136 Isopentane 0.970 8500.941 4.250 n-pentane 05301 72.15 0.0169 n-pentane 1.211 10608.165 5.304 cyclopentane 00325 70.15 0.0010 cyclopentane 0072 632.349 0.316 n-hexane 0104 86.18 0.0040 n-hexane 0.284 2485.913 1.243 cyclohexane 00232 84.18 0.0009 cyclohexane 0.062 541.680 0.271 Other hexanes 0.1554 86.18 0.0065 Other hexanes 0.462 4049.170 2.025 heptanes 00542 100.21 0.0028 heptanes 0.204 1784.400 0.892 methylcyclohexa 00147 98.19 0.0006 methylcyclohe 0.046 400.342 0.200 I 224-TMP 00001 114.22 0.0000 224-IMP 0.000 3.168 0.002 Benzene 00074 78.11 0.0003 Benzene 0.018 160.319 0.080 Toluene 00027 92.14 00001 Toluene 0.008 69.001 0.035 Ethylbenzene 00042 106.17 0.0000 Ethylbenzene 0.001 5.889 0.003 Xylenes 0001 106.17 0.0000 Xylenes 0.003 29.447 0.015 CBs-Heavies 00231 -2335.3467 -0.0239 CBs-Heavies -1.708 -14962.683 -7.481 Mass Fraction VOC: 0.2624 Total VOC 82.241 Heating Value I 1313 BTU/scf ComtoAnn emnsson factor source AP-42.Chapter 115 0.07 I0 N0x/MMefu 007 I IY COIMMBN I Notes Emissions Summary Table Pollutant Uncontrolled Emission Fac Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 15647.05lb/MMscf 782.35 lb/MMscf 82.2 tpy 4.1 tpy Gas Analysis Nos 007 lb/MMBTU 0.07 lb/MMBTU 0.5 tpy 0.5 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 2.6 tpy 2.6 tpy AP-42 Benzene 15.25 lb/MMscf 0.76 lb/MMscf 160 lb/yr 8 lb/yr Gas Analysis ' n-Hexane 236.48 lb/MMscf 11.82 lb/MMscf 2486 lb/yr 124 lb/yr Gas Analysis Toluene 6.56 lb/MMscf 0.33 lb/MMscf 69 lb/yr 3 lb/yr Gas Analysis Xylenes 280 lb/MMscf 0.14 lb/MMscf 29 lb/yr 1 lb/yr Gas Analysis Ethylbenzene 0.56 lb/MMscf 0.03 lb/MMscf 6 lb/yr 0 lb/yr Gas Analysis J Two separators controlled by 4 enclosed flares.Flares have a minimum combustion efficiency of 95%. The 012 flares are enclosed. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to a flare Natural gas venting from a well head separator.Emissions from this source are routed to a flare. 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-mop at 60F and 1 atm Throughput(0) 12.1 MMedyr 1381.278539 se M MW 32.8 Ibab-mol 0.033150885 MMacf/d _ J mole% MW 'Male! mass fraction IbM IIWT MY Helium 0.00 4.0028 0.000 0.000 0.00 0.00 0.00 CO2 2.69 44.01 1.184 0.036 4.31 37798.35 18.90 N2 0.19 28.013 0.053 0.002 0.19 1699.28 0.85 methane 38.05 16.041 6.103 0.186 22.24 194850.46 97.43 ethane 24.48 30.063 7.360 0.224 28.83 234991.41 117.50 propane 20.89 44.092 9.210 0.281 33.57, 294053.05 147.03 isobutane 2.32 58.118 1.350 0.041 4.92 43097.29 21.55 n-butane 8.83 58.118 3.968 0.121 14.48 128873.78 63.34 isopenane 1.25 72.114 0.899 0.027 3.28 28718.84 14.38 n-pentane 1.60 72.114 1.152 0.035 4.20 38779.57 18.39 cydopenane 0.11 70.13 0.077 0.002 0.28 2465.12 1.23 n-Hexane 0.33 88.18 0.288 0.009 1.05 9197.91 4.80 cydohexene 0.09 84.18 0.075 0.002 0.27 2398.72 1.20 Other hexane' 0.54 88.18 0.469 0.014 1.71 14978.58 7.49 heptanes 0.28 100.21 0.285 0.008 0.98 8452.59 4.23 metirylcydohelaia 0.07 98.19 0.089 0.002 0.25 2188.11 1.09 224TMP 0.00 114.23 0.000 0.000 0.00 7.29 0.00 Benzene 0.06 78.12 0.048 0.001 0.17 1518.89 0.76 Toluene 0.04 92.15 0.038 0.001 0.14 1223.87 0.61 Ethylbenzene 0.00 106.17 0.004 0.000 0.01 128.80 0.06 Xylenes 0.01 106.17 0.014 0.000 0.05 437.26 0.22 C8+Heavies 0.15 137.4837286 0.210 0.006 0.77 6720.05 3.36 VOC mass had 0.553 Total VOC(Uncontidled) 289.52 Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer Cimmaron and Leed Model 48"HVECD and L30-0010 Serial Number 59011404,20057,20053,21308 Gas Heating Value 1871 Btu/scf Throughput 22639.1 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales line. Make GasJack Model GJ230 Requested Control 100.00% Annual Bypass Tim 50.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 jIb NOX/MMBtu 0.37 IIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 47854.19 lb/MMscf 2392.71 lb/MMscf 289.5 tpy 14.5 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.8 tpy 0.8 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 4.2 tpy 4.2 tpy AP-42 Benzene 125.53 lb/MMscf 6.28 lb/MMscf 15191h/yr 76 lb/yr Gas Analysis n-Hexane 760.16 lb/MMscf 38.01 lb/MMscf 9198 lb/yr 460 lb/yr Gas Analysis Toluene 101.15 lb/MMscf 5.06 Ib/MMscf 1224 lb/yr 61 lb/yr Gas Analysis xylenes 36.14 lb/MMscf 1.81 lb/MMscf 437 lb/yr 22 lb/yr Gas Analysis Ethylbenzene 10.65 lb/MMscf 0.53 lb/MMscf 129 lb/yr 6 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 Section I A applies to all emission sources."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" 013 Flare stack.Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. Equipment Description This source vents natural gas front Emissions from this source are: routed to a flare Calculations Emission Calculation Metiod EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q•MW•Xx IC Ex=emissions of pollutant x Q=Volumetric flow ratelvolume 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-moo at B0F and 1 atm Throughout(0) 5.8 MMsdlyr 862.1004568 sd4r MW 22.2 lb/E-rrol 0.015890411 MMscvd mole% MW taxed mass traction Ibtr Iblyr tpy Helium 0.01 4.0026 0.000 0.000 0.00 8.13 0.00 CO2 2.11 4.01 0.929 0.042 1.82 14210.93 7.11 N2 0.49 28.013 0.137 0.006 0.24 2100.61 1.05 methane 70.35 16.041 11.285 0.508 19.71 172699.46 88.35 ethane 14.37 30.063 4.319 0.195 7.54 66093.23 33.05 propane 8.07 44.092 3.556 0.180 621 54424.70 27.21 Isobutane 0.84 58.118 0.491 0.022 0.88 7507.47 3.75 n-butane 2.35 58.118 1.368 . 0.062 2.39 20927.69 10.46 Ieopanta a 0.42 72.114 0.308 0.014 0.54 4688.06 2.34 n-pentane 0.53 72.114 0.382 0.017 0.67 5850.14 2.93 cydopentare 0.03 70.13 0.023 0.001 0.04 348.80 0.17 n-Haan 0.10 88.18 0.090 0.004 0.16 1371.60 0.69 cyddanane 0.02 84.18 0.020 0.001 0.03 298.80 0.15 Other hexaues 0.17 86.18 0.146 0.007 0.26 2234.13 1.12 heptanes 0.06 100.21 0.064 0.003 0.11 984.54 0.49 metirylcydohexae 0.01 98.19 0.014 0.001 0.03 220.89 0.11 224-TMP 0.00 114.23 0.000 0.000 0.00 1.75 0.00 Benzene 0.01 78.12 0.008 0.000 0.01 88.47 0.04 Twinkle 0.00 92.15 0.002 0.000 0.00 38.08 0.02 Ethytenzene 0.00 106.17 0.000 0.000 0.00 3.25 0.00 Xylenes 0.00 106.17 0.001 0.000 0.00 18.25 0.01 CS+Resides 0.02 137.4837288 0.032 0.001 0.08 488.02 0.24 VOC mass had 0.293 Total VOC(U conbdled) 49.75 !1912.6 Mole%,MW,and mass fractions from Critter Creek 2-03H gas analysis. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+based on the average MW on the analysis for the gas. Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer Model Serial Number Gas Heating Value 1292 Btu/scf Throughput 7493.6 MMBtu/yr VRU Information Equipment Description Engine to recompress gas to sales line. Make Model Requested Control 100.00% Annual Bypass Tim 50.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 lb NOX/MMBtu 0.37 (lb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 17153.56 lb/MMscf 857.68 lb/MMscf 49.7 tpy 2.5 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 Ib/MMBTU 0.3 tpy 0.3 tpy AP-42 CO 0.37 lb/MMBTU 0.37 Ib/MMBTU 1.4 tpy 1.4 tpy AP-42 Benzene 15.25 lb/MMscf 0.76 lb/MMscf 88 lb/yr 4 lb/yr Gas Analysis n-Hexane 236.48 lb/MMscf 11.82 lb/MMscf 1372 lb/yr 69 lb/yr Gas Analysis Toluene 6.56 lb/MMscf 0.33 lb/MMscf 38 lb/yr 2 lb/yr Gas Analysis xylenes 2.80 lb/MMscf 0.14 lb/MMscf 16 lb/yr 1 lb/yr Gas Analysis Ethylbenzene 0.56 lb/MMsd 0.03 lb/MMsd 3 lb/yr 0 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' 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