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Home My WebLink About20150517.tiff CDPHE ; COLORADO CO A Department of Public Health Et Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County-Clerk to the Board 1150OSt RECEIVED PO Box 758 Greeley.CO 80632 FEB i 8 2015 February 12, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On February 18. 2015.the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC—State Antelope P-16. 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 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 • �I g pF:CO 2-23- Pw 4L �5 4300 Cherry Creek Drive S., Denver, COO 80246.1330 P 303-692.2000 www.colorado.gov/cdphe r ho. John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer N. 2015-0517 CDPHE Air Pollution Control Division CO -1.1-• Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company LLC—State Antelope P-16—Weld County Notice Period Begins: February 18.2015 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: State Antelope P-16 oil and gas exploration and production facility 10.9 miles east of Kearsey.Colorado 80644 Weld County The proposed project or activity is as follows: Operator requests a permit for a facility consisting of six crude oil tanks, three produced water tanks,a crude oil truck loadout,fugitive emissions,two separators,a pump,and four enclosed flare stacks. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B. Section TII.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 14WE0196 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 address: Kirk Bear Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B1 Denver,Colorado 80246-1530 cdphe.commentsapcd@state.co.us itar COLORADO 1 I 0ewrc,n V rua,ic lOW,lrbEb,u.r.Mn. STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT c% AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 *4524; 4,896 x; CONSTRUCTION PERMIT PERMIT NO: 14WE0196 Issuance 1 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 State Antelope P-16 Production Facility, located in the NWNE, Section 16, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point TANKS 002 Six 500 barrel crude oil storage tanks PW 003 Three produced water tanks total 520 barrels TL 004 Truck crude oil loadout FUG 005 Fugitive equipment leaks SEP-1 and 006 Separator controlled by an enclosed flare stack. Flare has a SEP-2 minimum combustion efficiency of 95%. P-1 007 One Sandpiper G1F pneumatic pump used for water transfer Flare stack used to control natural gas flaring when sales gas FL-1 008 pipeline is down. Flare has a minimum combustion efficiency of 95%. The flare is enclosed. Point 007: 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 the Division. The Notice of Startup form may be downloaded online at AIRS ID: 123-9BDD Page 1 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division www.cdphe.state.co.us/ao/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 shallbe 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, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. 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. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days after issuance of permit. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. 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 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 Equipment ID Point NO, VOC CO Emission Type TANKS 002 3 Point AIRS ID: 123-9BDD Page 2 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division PW 003 1 Point TL 004 30.1 Point FUG 005 12 Fugitive SEP-1 and 006 0.9 18.9 4.9 Point SEP-2 P-1 007 0.2 2.4 1.3 Point FL-1 008 0.9 8.5 4.6 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 005: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 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 TANKS 002 Enclosed Flare VOC PW 003 Enclosed Flare VOC SEP-1 and 006 Enclosed Flare VOC SEP-2 P-1 007 Enclosed Flare VOC FL-1 008 Enclosed Flare VOC PROCESS LIMITATIONS AND RECORDS AIRS ID: 123-9BDD Page 3 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 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 TANKS 002 Oil Throughput 201480 bbl PW 003 Produced Water Throughput 153300 bbl TL 004 Oil Loaded 201480 bbl SEP-1 and 006 Gas Vented from Separator 13.2 MMscf SEP-2 P-1 007 Natural Gas 5.3 MMscf FL-1 008 Gas Vented from Sales Gas Line 18.5 MMscf 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. 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 and to calculate emissions as described in this permit. 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 11. 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) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. Point 002: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, 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 enclosed flare or combustion device, 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. 14. 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) AIRS ID: 123-9BDD Page 4 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 15. Point 004: 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): 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. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 16. Point 004: 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. 17. Point 005: 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. 18. 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. i. Auditory/visual/olfactory inspection (AVO) will be performed on a quarterly basis. ii. 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. 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. AIRS ID: 123-9BDD Page 5 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 19. Point 005: 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. OPERATING & MAINTENANCE REQUIREMENTS 20. 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 21. Point 008: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7, Section XVII.A.II) 22. 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 23. Point 005: On an annual basis, the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. AIRS ID: 123-9BDD Page 6 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division ALTERNATE OPERATING SCENARIOS 24. Point 007: 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. 25. Point 007: 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. 26. Point 007: 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 27. 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„) 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 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. AIRS ID: 123-9BDD Page 7 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 28. 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 29. 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. 30. 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. 31. 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. 32. 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. 33. 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 of a source may request a hearing before the AQCC for review of the Division's action. 34. 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. AIRS ID: 123-9BDD Page 8 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 35. 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 1 This Issuance Bonanza Creek Energy Operating Company LLC AIRS ID: 123-9BDD Page 9 of 14 • 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.aov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument C°/02FCBONAddLinkView&cid=12515993896418oacename=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. AIRS Uncontrolled Controlled Point Pollutant CAS# Emissions Reportable Emissions (Ib/yr) (Ib/yr) 002 Benzene 71432 974 Yes 49 002 n-Hexane 110543 6384 Yes 319 002 Toluene 108883 604 Yes 30 003 Benzene 71432 1073 Yes 54 003 n-Hexane 110543 3373 Yes 169 004 Benzene 71432 797 Yes 797 004 n-Hexane 110543 4291 Yes 4291 004 Toluene 108883 1759 Yes 1759 004 Ethylbenzene 100414 348 Yes 348 004 Xylenes 1330207 1178 Yes 1178 004 224 TMP 540841 524 Yes 524 005 Benzene 71432 229 No 229 005 n-Hexane 110543 656 Yes 656 006 Benzene 71432 792 Yes 40 . 006 n-Hexane 110543 4643 Yes 232 006 Toluene 108883 433 Yes 22 007 Benzene 71432 218 No 11 AIRS ID: 123-9BDD Page 10 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 007 n-Hexane 110543 1324 Yes 66 008 Benzene 71432 763 Yes 38 008 n-Hexane 110543 4623 Yes 231 008 Toluene 108883 522 Yes 26 5) The emission levels contained in this permit are based on the following emission factors: Point 002: Uncontrolled Pollutant Emission Factors Source lb/bbl Oil VOC 0.590 E&P TANK n-Hexane 0.032 E&P TANK Benzene 0.005 E&P TANK Toluene 0.003 E&P TANK Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 003: Uncontrolled Pollutant Emission Factors Source lb/bbl 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 004: Uncontrolled Emission Factors Pollutant lb/bbl loaded Source VOC 0.2991 AP-42 Benzene 0.0040 eng calc n-Hexane 0.0213 eng calc Toluene 0.0087 eng calc Xylenes 0.0059 eng calc E-Benzene 0.0017 eng calc 224-TMP 0.0026 eng calc 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) =7.51 psia M (vapor molecular weight) =64 Ib/Ib-mol T(temperature of liquid loaded) = 524 °R AIRS ID: 123-9BDD Page 11 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division Point 005: Component Gas Heavy Oil Light Oil Water/Oil Connectors 1217 0 571 467 Flanges 51 0 16 18 Open-ended Lines 37 0 6 1 Pump Seals 2 0 0 1 Valves 177 0 72 50 Other 86 0 8 18 VOC Content(wt. fraction) 0.29600 0 0.9966 1 Benzene Content(wt. fraction) 0.00070 0 0.0132 0.0012 Toluene Content(wt.fraction) 0.00050 0 0.0292 0.0003 Ethylbenzene(wt.fraction) 0.00005 0 0.0058 0.0001 Xylenes Content(wt. fraction) 0.00020 0 0.0196 0.0001 n-hexane Content(wt.fraction) 0.00400 0 0.0712 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 Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: Standard EFs-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 I from the most recent gas and liquids analyses. Point 006: Weight Fraction of Uncontrolled Pollutant Gas(%) Emission Factors Source Ib/MMscf NOx(lb/MMBTU) — 0.068 AP-42 CO(lb/MMBTU) - 0.370 AP-42 VOC 46.18 57163.5 Gas Analysis Benzene 0.10 59.9 Gas Analysis Toluene 0.08 32.8 Gas Analysis Ethylbenzene 0.01 3.3 Gas Analysis Xylenes 0.03 11.2 Gas Analysis n-hexane 0.63 351.7 Gas Analysis AIRS ID: 123-9BDO Page 12 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division Point 007: Uncontrolled Pollutant Emission Factors Source lb/MMscf NOx(lb/MMBTU) 0.068 AP-42 CO (lb/MMBTU) 0.37 AP-42 VOC 18265.7 Gas Analysis Benzene 41.2 Gas Analysis n-Hexane 249.8 Gas Analysis Toluene 28.2 Gas Analysis Xylenes 10.0 Gas Analysis Point 008: Weight Uncontrolled Pollutant Fraction of Emission Factors Source Gas (%) lb/MMscf NOx(lb/MMBTU) --- 0.068 AP-42 CO (lb/MMBTU) --- 0.370 AP-42 VOC 46.18 18306.33 Gas Analysis Benzene 0.10 41.22 Gas Analysis Toluene 0.08 28.20 Gas Analysis Ethylbenzene 0.01 3.08 Gas Analysis Xylenes 0.03 10.08 Gas Analysis n-hexane 0.63 249.89 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: http://ecfr.q poaccess.p ov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK AIRS ID: 123-9BDD Page 13 of 14 Colorado Department of Public Health and Environment Air Pollution Control Division 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 9) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: httn://www.colorado.00v/pacific/cdphe/air-nermit-self-certification AIRS ID: 123-9BDD Page 14 of 14 Division Information Engineer: Kirk Bear Control Engineer: Christopher Laplante Review Date: 12/29/2014 Application Date: 12/09/2013 Facility Identifiers Permit No. 14WE0196 AIRS County it 123 Weld Facility it 9BDD Facility Type: exploration and production facility O Looted in the 8-hour non-attainment area? O True Minor Q Synthetic Minor for r VOC r NOx r CO Administrative Information Company Name: Bonanza Creek Energy Operating Company,LLC Source Name: State Antelope P-16 Production Facility Source Location: NWNE,Section 16 SIC: 1311 Mailing Address 1: Bonanza Creek Energy Operating Company,LLC Address Address 2: 410 17th Street,Suite 1500 f,State Zip: Denver,Colorado 80202 Name: Peg Young Person To Phone: 720 440 6133 Contact Fax: 720 279 2331 Email: pvoungtaBonanzaCrk.com Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the State Antelope P-16 Production Facility,located in the NWNE,Section 16,Weld County,Colorado. Point Name Type Control Action Newly 002 TANKS Oil Tanks Flare reported source Newly 003 PW Water Tanks Flare reported source Newly 004 TL Loadout None reported source Newly 005 FUG Fugitives None reported source SEP-1 and Newly 006 SEP 2 Separator Venting Flare reported source Newly 007 P-1 Pump Flare reported source Newly 008 FL-1 Separator Venting Flare reported source Flare stack used to control natural gas flaring when sales gas pipeline is down.Flare has a minimum 008 combustion efficiency of 95%. The flare is enclosed. Equipment Description This source vents natural gas from: a natural gas pipeline Emissions from this source are: routed to a flare Natural gas venting from a natural gas pipeline.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=O•MW•Xx/C Ex=emissions of pollutant x O=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 sof/lb-mob at 60F and 1 atm Throughput(0) 18.5 MMsof/yr 2111.872148 scfmr MW 23.4 Ib/Ib-mol 0.050684932 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.01 4.0026 0.000 0.000 0.00 19.54 0.01 CO2 2.27 44.01 0.999 0.043 5.57 48765.17 24.38 N2 0.69 28.013 0.193 0.008 1.08 9434.99 4.72 methane 70.20 16.041 11.261 0.481 62.75 549682.98 274.83 ethane 13.39 30.063 4.024 0.172 22.42 196440.88 98.22 propane 8.52 44.092 3.754 0.160 20.92 183263.92 91.63 isobutane 0.84 58.118 0.488 0.021 2.72 23812.89 11.91 n-butane 2.54 58.118 1.474 0.063 8.21 71926.62 35.96 isopentane 0.44 72.114 0.315 0.013 1.76 15389.77 7.69 n-pentane 0.55 72.114 0.399 0.017 2.22 19451.94 9.73 cyclopentane 0.04 70.13 0.029 0.001 0.16 1434.33 0.72 n-Hexane 0.11 88.18 0.095 0.004 0.53 4823.14 2.31 cyclohexane 0.03 84.16 0.023 0.001 0.13 1148.15 0.57 Other hexanes 0.19 86.18 0.161 0.007 0.90 7841.24 3.92 heptanes 0.08 100.21 0.085 0.004 0.47 4148.01 2.07 methylcyclohexane 0.02 98.19 0.020 0.001 0.11 987.34 0.49 224-TMP 0.00 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.02 78.12 0.016 0.001 0.09 762.65 0.38 Toluene 0.01 92.15 0.011 0.000 0.06 521.78 0.26 Ethylbenzene 0.00 108.17 0.001 0.000 0.01 57.01 0.03 Xylenes 0.00 106.17 0.004 0.000 0.02 186.57 0.09 0.8+Heavies 0.05 137.4837288 0.064 0.003 0.38 3113.88 1.58 99.99 VOC mass fracl 0.297 Total VOC(Uncontrolled) 169.33 .Notes Mole%,MW,and mass fractions from Critter Creek 2-03H gas analysis. Emissions are based on 8780 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 TBD Model TBD Serial Number TBD Gas Heating Value 1352 Btu/scf Throughput 25012 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 Jib NOX/MMBtu 0.37 IIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 18306.34 lb/MMscf 915.32 lb/MMscf 169.33 tpy 8.47 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.85 tpy 0.85 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 4.63 tpy 4.63 tpy AP-42 Benzene 41.22 lb/MMscf 2.06 lb/MMscf 762.65 lb/yr 38.13 lb/yr Gas Analysis n-Hexane 249.90 lb/MMscf 12.49 lb/MMscf 4623.14 lb/yr 231.16 lb/yr Gas Analysis Toluene 28.20 lb/MMsd 1.41 lb/MMscf 521.78 lb/yr 26.09 lb/yr Gas Analysis Xylenes 10.08 lb/MMscf 0.50 lb/MMscf 186.57 lb/yr 9.33 lb/yr Gas Analysis Ethylbenzene 3.08 lb/MMscf 0.15 lb/MMscf 57.01 lb/yr 2.85 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" 007 One Sandpiper GlF pneumatic pump used for water transfer Pump Information Manufactur Sandpiper Model Number:GIF Serial Pump Number:2091612 Information Pump capacity 9.1 gallons per minute pumped natural gas 805 set/hour used consumptlo Control Flare 95.00%Efficieno7 Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=O•MW•Xx/C _ Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas a SG of gas•MW of air Xx=mass fraction of x in gas C=molar vdume of ideal gas(379 sd/lb-mol)at EOF and 1 atm O ass sd/hr MW 23.4 Ib/Ib-md Has,.crop 87001wrmr Requested Throughput 5.2998 MMscf/yr Component mole% MW massfraction Component lb/hr lb/yr spy CO2 227 44 0.0427 CO2 1.594 13966.861 6.983 nitrogen aes 28 0.0083 nitrogen 0.308 2701.639 1.351 methane 70.20 16.04 0.4812 methane 17.974 157455.258 78.728 ethane 13.39 30.07 0.1720 ethane 6.426 56288.638 28.144 • propane 8.52 44.09 0.1604 propane 5.993 52498.274 26.249 Isobdane 0.84 58.12 0.0208 isobutane 0.779 6822.049 3.411 n-butane 2.54 58.12 0.0630 n-butane 2.352 20805.937 10.303 Isopentane 0.44 72.15 0.0135 isopentane 0.504 4410.997 2.205 n-pentane 0.55 72.15 0.0170 n-pentane 0%36 5575.290 2788 cyclopentane 0.04 70.15 0.0013 cyclopentane 0.047 411.019 0.206 n-hexane 0.11 86.18 0.0040 n-hexane 0.151 1324.416 0.662 cyclohexane 0.03 84.18 0.0010 cydohexane 0.037 328.423 0.164 Otherhexanes 0.19 86.18 0.0069 Otherhexanes 0.256 2246.325 1.123 heptanes 0.08 100.21 0.0036 heptanes 0.136 1188.303 0.594 methylcyclohexa 0.02 98.19 0.0009 methylcyclohe 0.032 282.849 0.141 224-TMP 0.00 114.22 0.0000 224-IMP 0.000 0.000 0.000 Benzene 0.02 78.11 0.0007 Benzene 0.025 218.452 0.109 Toluene 0.01 92.14 0.0005 Toluene 0.017 149.461 0.075 EMylbenzene 0.00 106.17 0.0000 Etylbenzene 0.002 16.331 0.008 Xylenes 0.00 106.17 0.0002 Xylenes 0.006 53.447 0.027 C8+Heavies 0.05 10375932 0.0021 C8+Heavies 0.077 673.233 0.337 99.97956 ractlon VOC: 0.2958 Total VOC 48.402 Heating Value I 1352 BTU/scf I Combustion emaron/actor scarce: AP-42:Chapter 135 0.07 I n NOXMMBN 0.37 I in COmMBA times Male%.MW.am mass indices front Buffalo Ditch 1-32H hclily gee enmesh,dated 2/1R008 Emissions Summary Table • Pollutant Uncontrolled Emission Fac Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 18265.75 lb/MMsd 913.29 lb/MMscf 48.40 tpy 2.42 tpy Gas Analysis Nox 0.07 Ib/MMBIU 0.07 lb/MMBTU 0.24 tpy 0.24 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 1.33 tpy 1.33 tpy AP-42 Benzene 41.22 lb/MMscf 2.06 lb/MMsd 218.45 lb/yr 10.92 lb/yr Gas Analysis n-Hexane 249.90 Ib/MMsd 12.49 Ib/MMsd 1324.42 lb/yr 66.22 Ib/yr Gas Analysts Toluene 28.20 Ib/MMsd 1.41 Ib/MMsd 149.46 lb/yr 7.47 lb/yr Gas Analysis Xylenes 10.08 lb/MMsd 0.50 lb/MMsd 53.45 lb/yr 2.67 lb/yr Gas Analysis EMylbenzene 3.08 lb/MMscf 0.15 lb/MMsd 1%33 lb/yr 0.82 lb/yr Gas Analysis 006 Separator controlled by an enclosed flare stack.Flare has a minimum combustion efficiency of 95%. 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 0=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-mol)at 60F and 1 atm Throughput(0) 13.2 MMscf/yr 1506.849315 scf/hr MW 35.1 Ib/Ib-mol 0.036164384 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.50 44.01 1.100 0.031 4.37 38320.05 19.16 N2 0.12 28.013 0.034 0.001 0.13 1170.78 0.59 methane 27.61 16.041 4.428 0.126 17.61 154233.07 77.12 ethane 2628 30.063 7.902 0.225 31.42 275208.47 137.80 propane 29.60 44.092 13.052 0.372 51.89 454567.07 227.28 isobutane 277 58.118 1.609 0.046 6.40 56034.89 28.02 n-butane 8.10 58.118 4.707 0.134 18.71 163922.75 81.96 isopentane 1.05 72.114 0.760 0.022 3.02 26475.01 13.24 n-pentane 1.19 72.114 0.859 0.024 3.42 29923.47 14.96 cyclopentane 0.08 70.13 0.056 0.002 0.22 1954.02 0.98 n-Hexane 0.15 86.18 0.133 0.004 0.53 4643.35 2.32 cyclohexane 0.04 84.16 0.030 0.001 0.12 1040.56 0.52 Otherhexanes 0.29 86.18 0.247 0.007 0.98 8611.36 4.31 heptanes 0.10 100.21 0.098 0.003 0.39 3406.40 1.70 methylcyclohexane 0.02 98.19 0.022 0.001 0.09 752.36 0.38 224-TMP 0.00 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.03 78.12 0.023 0.001 0.09 791.75 0.40 Toluene 0.01 92.15 0.012 0.000 0.05 433.28 0.22 Ethylbenzene 0.00 106.17 0.001 0.000 0.01 44.37 0.02 Xylenes 0.00 106.17 0.004 0.000 0.02 147.91 0.07 C8+Heavies 0.04 137.4837288 0.052 0.001 0.21 1810.00 0.90 99.99 VOC mass fracl 0.617 Total VOC(uncontrolled) 377.28 Notes Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility. Manufacturer LEED Four Model L-30-0010 Serial Number 21293,21292,21134,21291 Gas Heating Value 2010 Btu/scf Throughput 26532 MMBtuyr VRU Information Equipment Description Engine to recompress gas to sales line. Make Model Requested Control 10.00% Annual Bypass Ti 50.00% Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 jib NOXIMMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 57163.53 lb/MMscf 2858.18 lb/MMscf 377.28 tpy 18.86 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 Ib/MMBTU 0.90 tpy 0.90 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 4.91 tpy 4.91 tpy AP-42 Benzene 59.98 lb/MMscf 3.00 lb/MMscf 791.751h/yr 39.59 lb/yr Gas Analysis n-Hexane 351.77 lb/MMscf 17.59 lb/MMscf 4643.35 lb/yr 232.17 lb/yr Gas Analysis Toluene 32.82 lb/MMscf 1.64 lb/MMscf 433.28 lb/yr 21.66 lb/yr Gas Analysis Xylenes 11.21 lb/MMscf 0.56 lb/MMscf 147.91 lb/yr 7.40 lb/yr Gas Analysis Ethylbenzene 3.36 lb/MMscf 0.17 lb/MMscf 44.37 lb/yr 2.22 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 idbwing 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." nos Fugitive equipment leeks Regulation 7 Information Operating Hours: 8760 hours/year Emission Factor Source Standard EFs-EPA-453/R-95-017 Table 2-4 Control Efficiency Source: Table 5-3 Monthly Monitoring Calculations Emission Factor(kglhr- Emissions Service Component Type Count source( Control(%)Pollutant Mass Fraction (tpy) Table 2-4 Table 24 Reg.3 Connectors 1217 2.OOE-04 1.00E-05 0.0% VOC 0296 5/174412 Flanges 51 3.90E-04 5.70E-06 0.0% Benzene 0.0007 0.0126115 Gas Open-Ended Lines 37 200E-03 1.50E-05 00% Toluene 0.0005 0.0091511 Pump Seals 2 240E-03 3.50E-04 0.0% Ethybenzene 000005 00009151 Valves 177 4.50E-03 2.50E-05 0.0% Xylenes 0.0002 00036604 Other 86 8.80E-03 1.20E-04 0.0% n-Hexane 0004 0.0732087 Connectors 0 7.50E-06 7.50E-06 0.0% VOC 0 0 Flanges 0 3.90E-07 3.90E-07 0.0% Benzene 0 0 Heavy 011 Open-Ended Lines 0 1.40E-0f 7.20E-06 0.0% Toluene 0 0 Pump Seals 0 0.00E+00 000E+00 0.0% Ethylbenzene 0 0 Valves 0 810E-06 8.40E-06 0.0% Xylenes 0 0 Other 0 3.20E-05 320E-05 0.0% n-Hexane 0 0 Connectors 571 2.10E-04 150E-06 0.0% VOC 0.9966 3561301 Flanges 16 1.10E-04 2.40E-06 00% Benzene 0.0132 00471695 Light 011 Open-Ended Lines 6 140E-03 140E-05 0.0% Toluene 0.0292 0.1043448 Pump Seals 0 1.30E-02 5.10EM 0.0% Ethyibenzena 0.0058 0.020726 Valves 72 250E-03 1.90E-05 0.0% XWenes 0.01% 00700396 Other 8 7.50E-03 1.10E-04 0.0% n-Hexane 00712 0.2544297 Connectors 467 1.10E-01 1.00E-05 0.0% VOC 1 29798506 Flanges 18 2.90E-06 2.90E-06 00% Benzene 0.0012 0.0035758 Water/Oil Open-Ended tines 1 2.50E-04 3.50E-06 00% Toluene 0.0003 0.000894 Pump Seals 1 240E-05 340E-05 0.0% Ethybenzene 0.0001 0.000298 Valves 50 9.80E-05 9.70E-06 0.0% Xylenes 0.0001 0.000298 - Other 18 110E.02 590E-05 00% n-Hexane 0.0001 0.000298 Emissions Summery Table Pollutant Uncontrolled Emissions Controlled Emissions Source VOC 120 tpy 12.0 tpy Standard EFs-EPA-453/R-95-017 Table 2-4 Benzene 127 lb/yr 127 lbM Standard EFs-EPA-453/R-95-017 Table 2-4 Toluene 229 lb/yr , 229 lb/yr Standard EFs-EPA-453/R-95-017 Table 2-4 Ethvbenzene 44 lb/yt 44 lb/yr Standard EFs-EPA-453/R-95-017 Table 2-4 XNenes 148 lb/yr 1481byr Standard EFs-EPA-453/R-95-017 Table 2-4 n-Hexane 656 lb/yr 656 lb/yr Standard EFs-EPA-453/R-95-017 Table 2.4 Regulatory Applicability If source is in non-attainment' Operator has agreed on the D'ivision's standard conditions for RACT. subpart KKK satisfies PACT. If source does not have an LDAR program or is subject to KKK.then Engineer needs to review and Reg.3 upon agreement between engineer.source,and supervisors for RACT Requirements(OWN plan satisfies RACT). The permit has RACT conditions that we are implementing if the operator Is not subject to KKK or doesn't have a 018M plan. 004 Truck Crude Oil 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 5 Saturation Factor 0.6 AP-42 P True Vapor Pressure 7.51 psia Sales Oil Analysis M Molecular Weight of Var 66.47 lb/lb-mole AP-42 T Liquid Temperature 524 deg.R Field Data L 7.12 lb/1000 gal 0.30 lb/bbl Annual requested Throughput 201480 BBL/yr 8462160 gal/yr Annual requested VOC emissions 60268 lb/yr 30.1 tpy Control: None Efficiency: 0.00% NCRPs Component Mass Fraction Benzene 0.0132 n-hexane 0.0712 Toluene 0.0292 Xylenes 0.0196 Ethyl ben 0.0058 224 TMP 0.0087 Source: Pressurized oil analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2991 lb/bbl 30.1 tpy 30.1 tpy AP-42 Benzene 0.0040 lb/bbl 797 lb/yr 797 lb/yr eng calc n-Hexane 0.0213 lb/bbl 4292 lb/yr 4292 lb/yr eng calc Toluene 0.0087 lb/bbl 1759 lb/yr 1759 lb/yr eng calc Xylenes 0.0058 lb/bbl 1178 lb/yr 1178 lb/yr eng calc Ethyl ben 0.0017 lb/bbl 348 lb/yr 348 lb/yr eng calc 224 TMP 0:0026 lb/bbl 524 lb/yr 524 lb/yr eng talc Regulatory Review 'Regulation 7-Volatile Organic Compounds This facility is not considered a bulk plant(in Reg. 7) because it does not distribute gasoline. 003 Three produced water tanks total 520 barrels Emissions Calculations Requsted Throughput 153300 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 20.1 tpy 1.0 tpy CDPHE Benzene 0.007 lb/bbl 1073 lb/yr 54 lb/yr CDPHE n-Hexane 0.022 lb/bbl 3373 lb/yr 169 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 II.A.5 -Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A-No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 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. 002 Six 500 barrel crude oil storage tanks Calculations Requsted Throughput 201480 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.59 lb/bbl 59.4 tpy 3.0 tpy E&P TANK Benzene 0.005 lb/bbl 1007 lb/yr 50 lb/yr E&P TANK n-Hexane 0.032 lb/bbl 6447 lb/yr 322 lb/yr E&P TANK Toulene 0.003 lb/bbl 604 lb/yr 30 lb/yr E&P TANK 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 II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. R ulation 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. R ulation 6-New S rce Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 19,800 gallons (471 bbl) NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. R ulation 7—Volatile O anic Com nds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks since it is crude oil.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this.) AIRS(County/Plant)123/9BDD Permit No. 14WE0196 Date 12/29/2014 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions Ctd. reportable Point 4 SCC Pollutant or CAS Factor Emisison Factor Source (tpy)' (tpy)' PTE(toy)* Eff% ? 002 VOC 14.048 lb/1000 qa ESP TANK 3 59.4 95% Yes 002 Benzene 0.119 lb/10O0 qa ESP TANK 50.4 1007.4 95% Yes 002 n-Hexane 0.762 lb/1000 ga E8P TANK 322.4 6447.4 95% Yes 003 40400315 VOC 6.238 lb/1000 qa CDPHE 1 20.1 95% Yes 003 40400315 Benzene 0.167 Ib/1000 qa CDPHE 53.7 1073.1 95% Yes 003 40400315 n-Hexane 0.524 Ib/1000 qa CDPHE 168.6 3372.6 95% Yes 004 40600132 VOC 7.122 lb/1000 qa AP-42 30.1 30.1 0% Yes 004 40600132 Benzene 0.095 lb/1000 qa enq calc 796.9 796.9 0% Yes 004 40600132 n-Hexane 0.507 lb/1000 qa enq calc 4292.2 4292.2 0% Yes 004 40600132 Toluene 0.208 lb/1000 ga eng calc 17593 1759.3 0% Yes 004 40600132 Xylenes 0.14 lb/1000 qa enq talc 1178.5 1178.5 0% Yes Standard EFs-EPA-453/R-95- 005 31000220 VOC 017 Table 2-4 12 12 0% Yes Standard EFs-EPA-453/R-95- 005 31000220 Benzene 017 Table 2-4 127.1 127.1 0% No Standard EFs-EPA-453/R-95- 005 31000220 n-Hexane 017 Table 2-4 655.9 655.9 0% Yes Standard EFs-EPA-453/R-95- 005 31000220 Toluene 017 Table 2-4 228.8 228.8 0% No Standard EFs-EPA453/R-95- 005 31000220 Ethylbenzene 017 Table 2-4 43.9 43.9 0% No Standard EFs-EPA453/R-95- 005 31000220 Xylenes 017 Table 2-4 148 148 0% No 006 31000205 VOC 57163.526 lb/MMscf Gas Analysis 18.9 377.3 95% Yes 006 31000205 NOx 0.068 lb/MMBTL AP-42 0.9 0.9 0% No 006 31000205 CO O371WMMBTL AP-42 4.9 4.9 0% Yes 006 31000205 Benzene 59.981 lb/MMsct Gas Analysis 39.6 791.8 95% Yes 006 31000205 n-Hexane 351.769 Ib/MMscf Gas Analysis 232.2 4643.4 95% Yes 006 31000205 Toluene 32.824 Ib/MMscf Gas Analysis 21.7 433.3 95% Yes 006 31000205 Ethylbenzene 3.362 lb/MMscf Gas Analysis 2.2 44.4 95% No 006 31000205 Xylenes 11.205 Ib/MMscf Gas Analysis 7.4 1479 95% No 007 31000299 VOC 18265.747 lb/MMscf Gas Analysis 2.4 48.4 95% Yes 007 31000299 NOx 0.068 lb/MMBT6 AP-42 0.2 0.2 0% No 007 31000299 CO 0.37 lb/MMBTL AP-42 1.3 1.3 0% Yes 007 31000299 Benzene 41.219 lb/MMscf Gas Analysis 10.9 218.5 95% No 007 31000299 n-Hexane 249.899 lb/MMscf Gas Analysis 66.2 1324.4 95% Yes 007 31000299 Toluene 28.201 lb/MMscf Gas Analysis 7.5 149.5 95% No 007 31000299 Ethylbenzene 3.081 lb/MMscf Gas Analysis 0.8 16.3 95% No 007 31000299 Xylenes 10.085 lb/MMscf Gas Analysis 2.7 53.4 95% No 008 31000205 VOC 18308.338 lb/MMscf Gas Analysis 8.5 169.3 95% Yes 008 31000205 NOx 0.068 lb/MMBTL AP-42 0.9 0.9 0% No 31000205 CO 0.37 Ib/MMBTU AP-42 4.6 4.6 0 Yes 31000205 Benzene 41.224 Ib/MMscf Gas Analysis 38.1 762.6 0.95 Yes 31000205 n-Hexane 249.899 Ib/MMscf Gas Analysis 231.2 4623.1 0.95 Yes 31000205 Toluene 28.204 lb/MMscf Gas Analysis 26.1 521.8 0.95 Yes 31000205 Ethylbenzene 3.081 lb/MMscf Gas Analysis 2.9 57 0.949 No 31000205 Xylenes 10.085 Ib/MMscf Gas Analysis 9.3 188.6 0.95 No Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) AIRS ID#': 123/9BDD - °°Z. ❑ APEN update only ® New or previously unreported battery ❑ Modification to existing sources ❑ Previously grandfathered battery' ❑ Registration for coverage under general permit no.GPOI O Synthetic minor facility ]LI WE-01 14 &cancellation request for individual pennit6: ® Located in the 8-hr Ozone Control Area ® Application for or Modification of an individual permit ❑ Registered under general permit no.GPOI ❑ Administrative permit amendment' ❑ Permitted under individual permit: ❑ Other: For individual permit applications,check if you wants: ®A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Name9: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 Mailing Address10: 410 171°Street,Suite 1500 City: Denver State: CO Zip: 80202 E-mail: pyoung@BonanzaCrk.com Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 Tank Battery Name": State Antelope P-16 Production Facility(COGCC#432999) Number of tanks: 6-500 bbl Location"(QQ Sec.Twp.Range.): NW/NE Sec 16,T5N R62W County: Weld Total tank capacity[bbl]: 3,000 Calendar year for which"Actual"data applies': 2013 Year(s)tank(s)were placed in service": 6-2013 Control Control Description": Four(4)Leed L30-0010 48"SNs:21293,21292,21134,21291 Efficiency": 95% Condensate Throughput'[bbl/year] Requested": 201,480 Maximum for PIT calculation": 201,480 Actual20: 167,900 While Controls Operational" 167,900 Other equipment at facility": Heater treaters,produced water tank,natural gas-feed engine,pneumatic pump Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emissions" Actual Emissions20 4 25 26 2J 26 2J / Pollutant" [lb/bbl] PTE Uncontrolled Controlled Uncontrolled Controlled VOC[tons/year] 0.59 59.26 59.26 X 2.96 / 49.38 ' 2.47 NOx[tons/year] 0.068 ' N/A 0.15 N/A 0.12 CO[tons/year] 0.37 N/A 0.79 N/A 0.66 Benzene[lbs/year] 0.005 973.7 973.7 48.7 811.4 40.6 - n-Hexane[lbs/year] 0.032 6,383.8 6,383.8 319.2 5,319.8 / 266.0 Wells serviced by this tank or tank batterys API#: 05-123-37403 Name: State Antelope 41-44-16HNB ®Newly Reported Well API#: 05-123-37404 Name: State Antelope 31-34-16HNB ®Newly Reported Well API#: Name: O Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name = ❑Newly Reported Well API#: Name: !''-]I: ❑Newly Reported Well API#: Name: ',,f ❑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 . If this is a re for coverage under general permit GPOI,I further certify that this source is and will be operated in full comp' e with a ch onditi a ral permit GPOI. Signature of Legally Aut rized Person(not a vendor or consultant) Date David J.Lillo II'F.:� Vice President,Rocky Mtn.Asset 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. Include Air Pollution Control Division,APCD-SS-BI (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South 302407 registration to: Denver,CO 80246-1530 FORM APCD-205 0 Page 1 of 2 (IRA Z dl(q FormAPCD-205-E&PCondensateTank Z M d t o o f oo a o. 6 `o Y <� a 0 R e ° oa .n _ = c R ❑ — o fi Z o v a M ri .r, d o R 0 °.: o. O -o as D m °' o45 . .n uc. a a ,� W > c d a" a E ❑ o 0 o C e o qA T c o2 m y P. .. S .. W m , m t+ �. Q O I. 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