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Home My WebLink About20203344.tiff xY COLORADO ill / 4 li Department of Public SDP"E Health&Environment RECEIVED Weld County - Clerk to the Board OCT 3 0 2020 1150 0 St WELD COUNTY PO Box 758 COMMISSIONERS Greeley, CO 80632 October 26, 2020 Dear Sir or Madam: On October 27, 2020, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company, LLC. - State Seventy Holes 21-6 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 Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 7.61.co<G\ •,�wr tiP\ 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe ,17 Jared Polls,Governor I Jill Hunsaker Ryan,MPH, Executive Director ,+ _._Wu r , %1* CCIPL(TP), HL-CDS), OG( fl), ,' `-Oblic -view 2020-3344 Pw M CSI£RIcH (C«) IL ( ICo(QO (MO 1QO Cr. 4410- Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public CDPHE Comment Website Title: Bonanza Creek Energy Operating Company, LLC. - State Seventy Holes 21-6 Production Facility - Weld County Notice Period Begins: October 27, 2020 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 Seventy Holes 21-6 Production Facility This facility is an oil and gas E&tP facility. Included emissions points are five low- pressure separators, condensate loadout to trucks, two 500 bbl produced water tanks, and ten 500 bbl condensate storage tanks. Lot 2, Section 6, T4N, R62W, Weld County, CO Weld County The proposed project or activity is as follows: This permit action establishes new synthetic minor limits, reduces throughput to AIRS 010 and 012, and updates emission factors for AIRS 010. Additionally, the GP07 under which AIRS 010 was operating has been cancelled and the associated limits added to this permit. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 15WE0363 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. Comments may be submitted using the following options: • Use the web form at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices. This page also includes guidance for public participation • Send an email to cdphe.commentsapcd@state.co.us • Send comments to our mailing address: Nicholas Dummer, P.E. COLORADO Department of Public 1 I Health b Environment Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 may,. COLORADO 2 Department of Public Health B Environment DPHE 14, Construction Permit Air Pollution Control Division Permit number: 15WE0363 Issuance: 4 Date issued: DRAFT Issued to: Bonanza Creek Energy Operating Company LLC Facility Name: State Seventy Holes 21-6 Production Facility Plant AIRS ID: 123-9D32 Physical Location: 40.34681, -104.3741, Lot 2, Section 6, T4N, R62W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment ID Point Equipment Description Description LPGFL 009 Five low-pressure separators Four enclosed combustors Four enclosed L-01 010 Condensate loadout to tanker trucks combustors and a vapor balance system PWT-01 011 Two 500 barrel produced water storage tanks Four enclosed combustors CNDTK-01 012 Ten 500 barrel condensate storage tanks Four enclosed combustors 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 this specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. This construction permit represents final permit approval and authority to operate this emissions source. Therefore, it is not necessary to self-certify. (Regulation Number 3, Part B, Section III.G.5.) EMISSION LIMITATIONS AND RECORDS 2. Emissions of air pollutants shall not exceed the following limitations. (Regulation No. 3, Part B, Section I I.A.4.) AIRS: 123-9D32 Page 1 of 12 15WE0363 Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point NOX VOC CO Type LPGFL 009 1.1 23.8 4.8 Point L-01 010 - 0.4 - Point PWT-01 011 0.1 0.2 0.1 Point CNDTK-01 012 0.4 10.4 1.6 Point Note: 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 not exceed 8.0 tons per year. Facility-wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility-wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 3. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation No. 3, Part B, Section Facility AIRS Pollutants Equipment ID Point Control Device Controlled LPGFL 009 Four enclosed combustors VOC and HAPs L-01 010 Four enclosed combustors and a vapor VOC and HAPs balance system PWT-01 011 Four enclosed combustors VOC and HAPs CNDTK-01 012 Four enclosed combustors VOC and HAPs PROCESS LIMITATIONS AND RECORDS 4. 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. (Regulation Number 3, Part B, II.A.4.) Process Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point LPGFL 009 Gas vented from separators 14.87 MMscf nnrrll COLORADO Airotintion Control Division *ep rment of Pu6k tea is b£roaonment Page 2 of 12 15WE0363 Facility AIRS Process Parameter Annual Limit Equipment ID Point L-01 010 Liquids loaded 65,700 bbl PWT-01 011 Produced water stored 23,214 bbl CNDTK-01 012 Condensate stored 65,700 bbl 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. 5. Point 009: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the separators 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 process limits specified in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 6. The permit number and ten-digit AIRS ID number assigned by the Division (i.e., 123-9D32-)ox) shall be marked on the subject equipment for ease of identification. (Reference: Regulation No. 3, Part B, III.E.) (State only enforceable) 7. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 8. Fugitive component leaks at this well production facility are subject to the Leak Detection and Repair (LDAR) program requirements including monitoring, repair, re-monitoring, recordkeeping, and reporting as described in Regulation No. 7, Section, Part D, Section II.E. In addition, the operator shall comply with the General Provisions contained in Regulation No. 7, Part D, Section II.B. 9. Points: 009, 010, 011, 012: The enclosed flares covered by this permit are subject to Regulation No. 7, Part D, Section II.B.2. 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 II, it must be enclosed; have no visible emissions during normal operations, as defined under Regulation Number 7, Part D, Section II.A.24; 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. This flare must be equipped with an operational auto-igniter according to the schedule in Regulation Number 7, Part D, Section II.B.2.d. 10. Points 009: The separators covered by this permit are subject to Regulation 7, Part D, Section II.F. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 11. Point 010: 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 COLORADO Air Pollution Control Division -„}, Page 3 of 12 15WE0363 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) 12. Point 010: 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.D.2): • Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other. liquid or vapor loss during loading and unloading. • All compartment hatches at the facility (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. • The owner or operator shall inspect onsite loading equipment at the time of inspection to monitor compliance with above conditions. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 13. Point 010: 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. 14. Point 010: Hydrocarbon liquids loadout from storage tanks to transport vehicles must be controlled by using (a) submerge fill and (b) a vapor collection and return system and/or air pollution control equipment. Compliance with Section II.C.5. must be achieved in accordance with the following schedule: (Regulation Number 7, Part D, Section II.C.5.a.) • Facilities constructed or modified on or after May 1, 2020 must be in compliance by commencement of operation. • Facilities constructed before May 1, 2020 must be in compliance by May 1, 2021. • Facilities not subject to Section II.C.5.a.(i)(A) or (B) that exceed the hydrocarbon liquids loadout to transport vehicles throughput of greater than or equal to 5,000 barrels per year on a rolling 12-month basis must control emissions from loadout upon exceeding the loadout threshold. 15. Point 010: Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 16. Point 010: The owner or operator must, as applicable: (Regulation Number 7, Part D, Section II.C.5.a.(iii)) • Install and operate the vapor collection and return equipment to collect vapors during the loadout of hydrocarbon liquids to tank compartments of outbound transport vehicles and to route the vapors to the storage tank or air pollution control equipment. • Include devices to prevent the release of vapor from vapor recovery hoses not in use. • Use operating procedures to ensure that hydrocarbon liquids cannot be transferred to transport vehicles unless the vapor collection and return system is in use. • Operate all recover and disposal equipment at a back-pressure less than the pressure relief vale setting of transport vehicles. • The owner or operator must inspect onsite loading equipment to ensure that hoses, couplings, and valves are maintained to prevent dripping, leaking, or other liquid or vapor loss during loadout. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. CDP.HEECOLORADO Air Pollution Control Division De o toLc,t,_ v E...r,: :,t Page 4 of 12 15WE0363 17. Point 010: The owner or operator must perform the following observations and training: (Regulation Number7, Part D, Section II.C.5.a.(iv)) • The owner or operator must observe loadout to confirm that all storage tanks operate without venting when loadout operations are active. These inspections must occur at least monthly, unless loadout occurs less frequently, then as often as loadout is occurring. • If observation of loadout is not feasible, the owner or operator must document the annual loadout frequency and the reason why observation is not feasible and inspect the facility within 24 hours after loadout to confirm that all storage tank thief hatches (or other access point to the tank) are closed and latched. • The owner or operator must install signage at or near the loadout control system that indicates which loadout control method(s) is used and the appropriate and necessary operating procedures for that system. • The owner or operator must develop and implement an annual training program for employees and/or third parties conducting loadout activities subject to Section II.C.5. that includes, at a minimum, operating procedures for each type of loadout control system. 18. Point 010: The owner or operator must retain the records required by Regulation Number 7, Part D, Section II.C.5.a.(v) for at least two (2) years and make such records available to the Division upon request. • Records of the annual facility hydrocarbon liquids loadout to transport vehicles throughput. • Inspections, including a description of any problems found and their resolution, required under Section II.C.5.a.(iii) and (iv) must be documented in a log. • Records of the infeasibility of observation of loadout. • Records of the frequency of loadout. • Records of the annual training program, including the date and names of persons trained. 19. Point 010: Air pollution control equipment used to comply with this Section II.C.5. must comply with Section II.B., be inspected in accordance with Section II.C.1.d.(ii) through (v), and achieve a hydrocarbon control efficiency of 95%. (Regulation Number 7, Part D, Section II.C.5.a.(vi)) 20. Point 012: This source is subject to Regulation Number 7, Part D, Section I. The operator must comply with all applicable requirements of Section I and, specifically, must: • Comply with the recordkeeping, monitoring, reporting and emission control requirements for storage tanks; and • Ensure that the combustion device controlling emissions from the storage tanks 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 combustion device, or by other means approved by the Division, determine whether it is operating properly (Regulation Number 7, Part D, Section I.C.) (State only enforceable) 21. Point 012: The storage tanks covered by this permit is subject to the emission control requirements in Regulation Number 7, Part D, Section II.C.1. The owner or operator must install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons except where the combustion device has been authorized by permit prior to March 1, 2020. The source must follow the inspection COLORADO 4 w� `Air Pollution Control Division s,.- Page 5 of 12 15WE0363 requirements of Regulation Number 7, Part D, Section II.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control requirement must be met within 90 days of the date that the storage tank commences operation. 22. Point 012: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Part D, Section II.C.2. 23. On or before June 30th, 2021 (and on June 30th each year thereafter), the owner or operator of oil and natural gas operations and equipment at or upstream of a natural gas processing plant in Colorado must submit a single annual report that includes actual emissions and specified information in the Division-approved report format. The information included in the annual report must be in accordance with the general reporting requirements of Regulation Number 7, Part D, Section V.B. Beginning July 1, 2020, and each calendar year thereafter, owners or operators must maintain the information according to Regulation Number 7, Part D, Section V.C. for inclusion in the annual report. (Regulation Number 7, Part D, Section V) OPERATING Et MAINTENANCE REQUIREMENTS 24. Points 009, 010, 011, 012: 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) 25. Point 010: The owner or operator of a loadout at which vapor balancing is used to control emissions shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks and return these vapors to the stationary source storage tanks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs 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. g. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 26. There are no initial testing requirements. Periodic Testing Requirements 27. This source is required to conduct periodic testing per the operating and maintenance plan. CDP}FE ( COLORADO COW Air Pollution Control Division Page 6 of 12 15WE0363 ADDITIONAL REQUIREMENTS 28. All previous versions of this permit are cancelled upon issuance of this permit. 29. This permit replaces the following permits which are cancelled upon issuance of this permit. Existing Permit Existing Emission Number Point New Emission Point GP07 123-9D32-010 123-9D32-010 30. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • 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 (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NOX 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 31. The requirements of Colorado Regulation Number 3, Part D must apply at such time that any stationary source or modification becomes a major stationary source or major modification solely by virtue of a relaxation in any enforceable limitation that was established after August 7, 1980, on the capacity of the source or modification to otherwise emit a pollutant such as a restriction on hours of operation (Regulation Number 3, Part D, Section VI.B.4/V.A.7.B). With respect to this Condition, Part D requirements may apply to future modifications if emission limits are modified to equal or exceed the following threshold levels: Emissions - tons per year Facility AIRS Equipment Current p Equipment Point Description Pollutant ID Threshold Permit Limit "HE , COLORADO y Air Pollution Control.DivisCO io Page 7 of 12 15WE0363 LPGFL 009 Low-pressure separators L-01 010 Condensate loadout PWT-01 011 Produced VOC 50 35.1 water tanks NOx 50 1.6 CNDTK-01 012 Condensate tanks Insignificant Sources Note: APEN and permit exempt sources do not have permit limits. However, the PTE of these sources (excluding fugitives) is still considered in the project increase when evaluating PSD and NANSR. 32. GENERAL TERMS AND CONDITIONS 33. 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 Number 3, Part B, Section II.B. upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. 34. 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 Number 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. 35. 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. 36. 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. 37. 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. 38. 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 ww,DP IC LORAD0 i Air Pollution Control Division 4 I cae u,Y<To,,tu,_ Page 8 of 12 15WE0363 in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 39. 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: Nicholas Dummer, P.E. Permit Engineer Permit History Issuance Date Description Issued to Bonanza Creek Energy Operating Company Issuance 1 April 20, 2016 LLC. Facility-wide construction permit for a synthetic minor facility. Combined point 008 (VRT) into point 009. Increased September 20, permit limits for point 009. Decreased permit limits Issuance 2 2016 for points 010, 011, and 012. No change to points 005 and 006. Facility is synthetic minor. Issued as Initial Approval. Cancellation of points 005 and 006. Removal of vapor Issuance 3 February 28, 2017 recovery tower. Adjust emission factors and emissions as requested. Cancellation of the GP07 associated with point 010. Reduction in throughput for points 010 and 012 and Issuance 4 This issuance change in EF for point 010. Updates to associated CO Reg. 7 requirements and citations for all equipment per rule changes in February 2020. 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. (Regulation Number 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. s DP s COLORADO Air Pollution Control uzvSsxsrn h.-4t.- Page 9 of 12 15WE0363 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: https://www.colorado.gov/pacific/cdphe/aqcc-regs 4) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 5) 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 Emissions (lb/yr) (lb/yr) Benzene 71432 2985 149 Toluene 108883 3496 175 Ethylbenzene 100414 812 41 009 Xylenes 1130207 1462 73 n-Hexane 110543 21012 1051 2,2,4 IMP 540841 2945 147 Benzene 71432 27 1 010 n-Hexane 110543 237 12 Benzene 71432 307 15 011 n-Hexane 110543 964 48 Benzene 71432 3351 168 Toluene 108883 2924 146 Ethylbenzene 100414 388 19 012 Xylenes 1130207 940 47 n-Hexane 110543 22719 1136 2,2,4 TMP 540841 2109 105 Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year (lb/yr) are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 6) The emission levels contained in this permit are based on the following emission factors: Point 009: Weight Uncontrolled Emission CAS # Pollutant Fraction Source of Gas (%) Factors (lb/MMscf) COLORADO i Air Pollution Control Division r.� t-„r,FF,t Page 10 of 12 15WE0363 Weight Uncontrolled Emission CAS # Pollutant Fraction Source of Gas (%) Factors (Ib/MMscf) N0x Ib/MMBtu --- 0.068 AP-42 CO lb/MMBtu --- 0.31 AP-42 V0C 65.95 63960 Bonanza/Promax 71432 Benzene 0.2069 200.8 Bonanza/Promax 108883 Toluene 0.2422 235.0 Bonanza/Promax 100414 Ethylbenzene 0.0564 54.72 Bonanza/Promax 1330207 Xylene 0.1014 98.38 Bonanza/Promax 110543 n-Hexane 1.4565 1413 Bonanza/Promax 540841 2,2,4 TMP 0.2041 198.0 Bonanza/Promax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 010: Uncontrolled Emission CAS# Pollutant Source Factors (lb/1000 gal) V0C 5.62 APCD EF N0x lb/MMBtu 0.068 AP-42 CO lb/MMBtu 0.31 AP-42 71432 Benzene 0.01 APCD EF 110543 n-Hexane 0.085 APCD EF Note: The controlled emissions factors for this point are based on a control efficiency of 95% Point 011: Uncontrolled CAS# Pollutant Emission Factors Source (lb/bbl) V0C 0.262 CDPHE 71432 Benzene 0.007 CDPHE 110543 n-Hexane 0.022 CDPHE Note: The controlled emissions factors for this point are based on a control efficiency of 95%. Point 012: Uncontrolled CAS# Pollutant Emission Factors Source lb/bbl N0x lb/MMBtu 0.068 AP-42 CO Ib/MMBtu 0.31 AP-42 V0C 6.3425 Bonanza/Promax 71432 Benzene 0.0510 Bonanza/Promax 108883 Toluene 0.0445 Bonanza/Promax 100414 Ethylbenzene 0.0059 Bonanza/Promax 1330207 Xylene 0.0143 Bonanza/Promax 110543 n-Hexane 0.3458 Bonanza/Promax 540841 2,2,4 TMP 0.0321 Bonanza/Promax Note: The controlled emissions factors for this point are based on a control efficiency of 95%. DPI COLORADO to Aix Pollution Control Division Page 11 of 12 15WE0363 7) 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. 8) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC MACT HH Area Source 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://www.ecfr.qov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A - Subpart UUUU NSPS Part 60, Appendixes Appendix A-Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart AA - Subpart DDD MACT 63.1200-63.1439 Subpart EEE- Subpart PPP MACT 63.1440-63.6175 Subpart QQQ- Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ - Subpart MMMMM MACT 63.8980-End Subpart NNNNN - Subpart XXXXXX sa COLORADO Air Pollution Control Division _ .. o:TVhtPubR ,ea,.,&trz„gin ,.; Page 12 of 12 ,..,T.z3,.-t 49ik+:5 1' .Ci.s l}• Section 01-Administrative Information Facility Alps ID: County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit "i' '" fp 1T4aS$1ad-- tank rttia fk& • Description: Emission Control Device l t'Yocla5gtf Description: Is this loadout controlled? Requested Overall VOC&HAP Control Efficiency%: RD Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Hydrocarbon Loadout Actual Volume Loaded= • -.65,700 Barrels(bbl)per year 'Requested Permit Limit Throughput= ••. • .Oa0f1 Barrels(661)per year Requested Monthly Throughput= 5-SC Barrels(bhl)per month Potential to Emit(PTE)Volume Loaded= D Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heat content of waste gas= 204 Btu/scf Actual Volume of waste gas emitted per year= .. scf/year Requested Volume of waste gas emitted per year= scf/year Actual heat content of waste gas routed to combustion device= MM BTU per year Requested heat content of waste gas routed to combustion device= MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= s• MMBTU per year Control Device Pilot Fuel Use Rate: :---:'1t scfh 'MMscf/yr These pilot emissions are accounted for in the storage tank section Pilot Fuel Gas Heating Value: t#Btu/scf .. MMBTU/yr Section 04-Emissions Factors&Methodologies Does the company use the state default emissions factors to estimate emissions? a Does the hydrocarbon liquid loading operation utilize submerged fill? 'has-a_.atn ny�„:-v_•..is5i s� . ,sea,, . .,..,s, ........: .... ..c.. .. Hydrocarbon Loadout Uncontrolled Controlled Emission Factor Source Pollutant (lb/bbl) (113/1361) (Volume Loaded) (Volume Loaded) IMENCEEIM s Qut9'Ur ® Pollutant Uncontrolled Uncontrolled Emission Factor Source (l6/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) =ME= _ %:.. Pilot Light Emissions Uncontrolled Uncontrolled Pollutant (Ib/MMetu) (lb/MMscf) Emission Factor Source (Pilot Gas (Waste Heat Combusted) Throughput) 'CS.. ®' , • OMIAf. y , ;,. H. •. - ..s 1 of 2 C:\Users\ndummer\Desktop\123-9032\15WE0363,CP4 Hydrocarbon Loadout Emissions Inventory Section 05-Emissions Inventory Potential to Emit Actual Emissions Requested Permit Limits Requested Monthly Limits Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) (lbs/month) PM10 0.00 0.00 0,0 0.00 0.00 3 PM2.5 0.00 0.77 0.00 0.00 0.00 SOx 5.00 0.00 0.00 0,00 0 NOx 0.01 0.01 0.00 0,00 ._ VOC .00 0.30 7.75 0.39 03 CO 0"05 ...3 0.0-0 0.03 0.05 Potential to Emit Actual Emissions Requested Permit Limits Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (Ibs/year) (Ibs/year) (Ibs/year) (Ihs/year) (Ibs/yearl Benzene 50 27 1 27 Toluene 0 0 0 0 . Ethylbenzene 7 0 0 0 Xylene 0 0 0 0 n-Hexane 442 211 12 237 224TMP 0 0 Section 06-Regulatory Summary Analysis Regulation 3,Parts A,B Source requires a per m',E Regulation 7 Part D Section II.C.5. The hydrocarbon liquids cadcut source is subject tc Begulat on 7 Par O SK ion II.C,5. (See regulatory applicability worksheet for detailed analysis) Section 07-Initial and Periodic Sampling and Testing Requirements Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes,the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08-Technical Analysis Notes These numbers match what was provided by the Source in their application.Note that pilots ght emissions are captured by the 012 storage tank point(shared control device). ` Section 09-SCC Coding and Emissions Factors(For Inventory Use Only) Uncontrolled ' Emissions AIRS Point St Process SCC Code - Pollutant Factor Control% Units 010 01 4-06-00--2 Crude 0u,Sabrr,erged Lozdrg Balanced rrr(0=tj PM10 7.,.. 0 lb/1,000 gallons transferred PM2.5 0.00 0 lb/1,000 gallons transferred SOx 0.00 0 lb/1,000 gallons transferred NOR 0.00 0 lb/1,000 gallons transferred VOC 5.0 95 lb/1,000 gallons transferred CO 0.04 0 lb/1,000 gallons transferred Benzene 0.01 45 lb/1,000 gallons transferred Toluene 0.00 35 lb/1,000 gallons transferred Ethylbenzene 0.00 05 lb/1,000 gallons transferred Xylene 0.00 95 lb/1,000 gallons transferred n-Hexane 0,09 -0 lb/1,000 gallons transferred 224 TMP 0.00 35 lb/1,000 gallons transferred 2 002 C:\Users\ndummer\Desktop\123-9 D32't15W E0363.CP4 Hydrocarbon Liquid Loading APEN C (f4�4y ..i�Y4e Form APCD-208 CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal wilt require payment for a new filing fee. This APEN is to be used for hydrocarbon liquid loading only. If your emission unit does not fall into this category, there may be a more specific APEN for your source(e.g. amine sweetening unit, glycol dehydration unit, condensate storage tanks, etc.). In addition, the General APEN (Form APCD-2OO)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms can be found on the Air Pollution Control Division(APCD)website. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 15WE0363 AIRS ID Number: 123 / 9D32 /010 Section 1 -Administrative Information Company Name: Bonanza Creek Energy Operating Company,LLC(BCEOC) / Site Name: State Seventy Holes 21-6 Production Facility(COGCC#438056) Site Location Site Location: 40.34681, -104.3741 County: Weld Lot 2, 4N, 6, 62W NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E-Mail Address2: asoehner@bonanzacrk.com 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices wilt be issued by the APCD via e-mail to the address provided. 431100 COLORADO Deponment d !With .. - _ ! th inw.unmem Permit Number: 15WE0363 AIRS ID Number: 123 /9D32/010 Section 2 - Requested Action ❑ NEW permit OR newly-reported emission source ❑ Request coverage under construction permit O Request coverage under General Permit GP07 If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- Q MODIFICATION to existing permit(check each box below that applies) O Change fuel or equipment O Change company name3 0 Change permit limit ❑ Transfer of ownership4 O Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS- El Limit Hazardous Air Pollutants (HAPs)with a federally-enforceable limit on Potential To Emit (PTE) Additional Info& Notes: Requesting new throughput and emission limits based on state emission factors. 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: Truck loadout used to load condensate from site. Company equipment Identification No. (optional): L-01 For existing sources, operation began on: 11/21/2014 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No Is this equipment located at a stationary source that is considered a Major Source of(HAP) ❑ Yes E] No emissions? Does this source load gasoline into transport vehicles? ❑ Yes 0 No Is this source located at an oil and gas exploration and production site? 0 Yes O No If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual 0 Yes O No average? Does this source splash fill less than 6,750 bbl of condensate per year? 0 Yes O No ' Does this source submerge fill less than 16,308 bbl of condensate per year? ❑ Yes 0 No COLORADO Permit Number: 15WE0363 AIRS ID Number: 123 /9D32/010 Section 4 - Process Equipment Information Product Loaded: ❑ Condensate O Crude Oil O Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded': 65,700 bbl/year Actual Volume Loaded: 65,700 bbl/year This product is loaded from tanks at this facility into: tank trucks (e.g. "rail tank cars"or"tank trucks") If site specific emission factor is used to calculate emissions,complete the following: Saturation Factor: Average temperature of F bulk liquid loading: Molecular weight of True Vapor Pressure: Psia @ 60 `F lb/lb-mol displaced vapors: If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded': bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft' Load Line Volume: ft3/truckload Vapor Recovery Line Volume: ft3/truckload 'Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.34681,-104.3741 O Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Discharge Height Above Temp. Flow Rate Velocity Stack ID No. Ground Level(Feet) ('F) (ACFM) (ft/sec) ECD 01-04 -25 500 TBD TBD Indicate the direction of the stack outlet: (check one) ✓❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal O Other(describe): Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): 48 ❑Square/rectangle Interior stack width(inches): Interior stack depth (inches): ❑Other(describe): Ase _ _ COLORADO a wdK Permit Number: 15WE0363 AIRS ID Number: 123 /9D32/010 Section 6 - Control Device Information 0 Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. Loading occurs using a vapor balance system: Requested Control Efficiency: 100 Used for control of: VOC,HAPs Rating: 0.04 MMBtu/hr Combustion Type: Enclosed Combustor Make/Model: Four(4)LEED L30-0011 Device: Requested Control Efficiency: 95 % Manufacturer Guaranteed Control Efficiency: 98 % Minimum Temperature: 500 F Waste Gas Heat Content: 2,884 Btu/scf Constant Pilot Light: 0 Yes El No Pilot Burner Rating: N/A MMBtu/hr Pollutants Controlled: 0 Other: Description: Requested Control Efficiency: Section 7 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies(report the overall, or combined, values if multiple emission control methods were identified in Section 6): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) PM SOx NO. CO VOC ECD 100 95 HAPs ECD 100 95 Other: ❑Q Using State Emission Factors(Required for GP07) VOC Benzene n-Hexane ❑� Condensate 0.236 Lbs/BBL 0.00041 Lbs/BBL 0.0036 Lbs/BBL O Crude 0.104 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)s Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Units (AP-42, Emissions Emissions6 Emissions Emissions Basis Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) PM 40.0 uglL AP-42 0 002 0.002 0 002 0 002 SOx 0.00020 Ib/MMBtu AP-42 <0.001 <0.001 <0.001 <0 001 NOx 0.068 Ib/MMBtu AP-42 0.012 0.012 0.012 0.012 CO 0.310 Ib/MMBtu AP-42 0.053 0.053 0.053 0.053 VOC 0 236 lb/bbl State EF 7 77 0.39 7.77 0.39 5 Requested values will become permit limitations or will be evaluated for exempt status, as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. .. - .COLORADO 1 Xsa'M b in�,rmmm, Permit Number: 15WE0363 AIRS ID Number: 123 /9D321010 Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteriaO Yes 0 No pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor Actual Annual Emissions Chemical Name Abstract Uncontrolled Source Uncontrolled Controlled Service(CAS) Basis Units (AP-42, Emissions Emissions& Number Mfg.,etc.) abs/year) (lbs/year) Benzene 71432 Toluene 108883 Ethylbenzene 100414 Xylene 1330207 n-Hexane 110543 2,2,4-Trimethylpentane 540841 Other: 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP07, I further certify that this source is and will be operated in full compliance with each condition of General Permit GP07. C2,/.t_ <�/v 5/04/2020 Signature of Legally Authorized Person(not a vendor or consultant) Date Alisson Soehner Environmental Engineer, Air Quality Name(print) Title Check the appropriate box to request a copy of the: El Draft permit prior to issuance 0 Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692.3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment ._ _. COLORADO Bonanza 410 17th Street,Suite 1400 Denver,CO 80202 CREEK (720)O5-0802 axone May 5, 2020 Stefanie Rucker Colorado Department of Public Health and Environment Air Pollution Control Division, APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 RE: Permit Modifications—CNDTK&TLO State Seventy Holes 21-6 Production Facility (COGCC#438056,AIRS ID: 123!9D32) Bonanza Creek Energy Operating Company, LLC Weld County, CO Ms. Rucker, Bonanza Creek Energy Operating Company, LLC (BCEOC) is pleased to submit the attached APENs and supporting documentation for the condensate tank battery(CNDTK-01,AIRS Point 012)and the truck loadout(L-01,AIRS Point 010)at the State Seventy Holes 21-6 Production Facility (COGCC#438056, AIRS ID: 123/9D32). BCEOC is requesting new throughputs for each source, as well as an updated collection efficiency for the truck loadout. In addition to the APENs, emissions calculations, and all other required documentation, a check covering two(2)APEN filing fees totaling$382.26 is included herein. If you need additional information regarding this modification application, please contact me at(303) 803- 1752 or via email at asoehner@bonanzacrk.com. Sincerely, Alisson Soehner Environmental Engineer,Air Quality Attachments: As stated cc: File • CORPORA F OFFI(F 41017"Street,Suite 14(X) Denier.CO 110202 Office (720)44(-010X1 CDPHE COLORADO -5 Form APCD-100 CODepartment of Public Health & Environment Oil & Gas Industry Construction Permit Application Completeness Checklist Ver.November 29,2012 Company Name: Bonanza Creek Energy Operating Company, LLC (BCEOC) Source Name: State Seventy Holes 21-6 Production Facility (C0GCC #438056) Date: May 2020 Yes No Are you requesting a facility wide permit for multiple emissions points? El ❑ In order to have a complete application,the following attachments must be provided, unless stated otherwise. If application is incomplete, it will be returned to sender and filing fees will not be refunded. Attachment Application Element Applicant APCD A APEN Filing Fees El ❑ B Air Pollutant Emission Notice(s)(APENs)& ❑ Application(s)for Construction Permit(s)—APCD Form Series 200 C Emissions Calculations and Supporting Documentation Q ❑ D Company Contact Information - Form APCD-101 Q ❑ E Ambient Air Impact Analysis El ❑ ❑ Check here if source emits only VOC (Attachment E not required) F Facility Emissions Inventory—Form APCD-102 ❑ nCheck here if single emissions point source(Attachment F not required) G Process description, flow diagram and plot plan of emissions unit and/or ❑ ❑ facility nCheck here if single emissions point source(Attachment G not required) N Operating& Maintenance (O&M) Plan—APCD Form Series 300 Q ❑ n Check here if true minor emissions source or application is for a general permit(Attachment H not required) I Regulatory Analysis Q ❑ n Check here to request APCD to complete regulatory analysis (Attachment 1 not required) Colorado Oil and Gas Conservation Commission (COGCC) 805 Series Rule © ❑ Requirements—Form APCD-105 Check here if source is not subject to COGCC 805 Series requirements (Attachment J not required) Send Complete Application to: Colorado Department of Public Health&Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver,Colorado 80246-1530 Check box if facility is an existing Title V source: n Send an additional application copy Check box if refined modeling analysis included: n Send an additional application copy Check box if application is for major NA NSR or PSD permit: n Send eight(8)total application copies Page 1 of 1 FormAPCD-100-AppCompleteChecklist-Ver.11-29-2012.docx Bonanza Creek Energy Operating Company,LLC.-State Seventy Holes 21-6 Production Facility(COGCC 6438056) VOC Emissions from Truck Loading(AP-42 Chapter 5.2(1/95)) uncontronea Saturation True Vapor Molecular Vapor VOC Loading Loss Collection Control Controlled Factor Pressure(P) Weight(M) Bulk Temp. Content(C) (LL)°4 Uncontrolled Efficiency(`) Efficiency VOC Site Product Loading Mode Sales (S)IN [psia] [lb/lb-moll (T)[F] [wt%] [Iblbbl] VOC Emissions [I] [%) Emissions Submerged loading dedicated vapor balance State Seventy Holes 21-6 Condensate service 65,700 bbl/year 1 N/A N/A 64 100.00% 0.236 7.77 tpy 100.0% 95.0% 0.39 tpy (a) Source:AP-42 Table 5.2-1(1/95) (b) Equation 1 for loading losses: IC)•(12.46)•(SPM(T)•W=L, Where. . L,=loading losses,lbs/1000 gal of liquid loaded S=saturation factor P=true vapor pressure of liquid loaded(psia)based on regression analysis for crude oil(AP 42 Chapter 7.1 page 56)and a raid vapor pressure of 0 0 psia M=true vapor pressure of liquid loaded(lb/lb-mole)based on intepola5on of Table 7.1-2 of AP 42 and a reid vapor pressure of 0.0 psia T=temperature of bulk liquids loaded"R("F=460)born EPA TANKS Meteorological Database for Denver,CO (c) Based on all tanker trucks having 70%(Basic)and the collection effeciendes in AP 42 Chapter 5.2,page 5.2-6 • AP-42 Chapter 5.2,Table 5.2-1(1/95) Submerged loading of a clean cargo tank 0.5 Wt.%of Loading Loss HAP THC(4j lb/bbl Uncontrolled HAP Emissions(°) Controlled HAP Emissions t°) Submerged loading:dedicated normal service(default) 0.6 Benzene I 0.1734% 0.0004 28.00 lb/yr 0.014 tpy 2.00 lb/yr i 0.001 tpy Submerged loading:dedicated vapor balance service 1.0 _ Toluene 0.0000% 0.0000 0.00 lb/yr 0.000 tpy 0.00 lb/yr 1 0.000 tpy Splash loading of a clean cargo tank 1.45 Ethylbenzene 0.0000% a0000 0.00 Ib/yr i 0.000 tpy 0.00 lb/yr � 0.000 tpy Splash loading:dedicated normal service 1.45 Xylenes 00000% 0.0000 0,00 Ib/yr 0.000.tpy ___. 0.00 Ib/yr I 0.000 tpy Splash loading:dedicated vapor balance service 1 n-Hexane I 1.5225% 0.0036 238.00 lb/yr 0.119 tpy 12.00 lb/yr 4 0.006 tpy Marine vessels Submerged loading.ships 0.2 2,2,4-Trimethylpentane 0.0000% 0.0000 0.00 lb/yr 0.000 tpy 0.00(b/yr ; 0.000 tpy Submerged loading:barges 0.5 Total 266.00 lb/yr N I 0.13 tpy 14.00 lb/yr j 0.01 tpy (d)Based on Condensate Composition (e) HAP Emissions,tpy=(VOC Emissions,tpy)'(HAP 1M.%of THC) Bonanza Creek Energy Operating Company,LLC.-State Seventy Holes 21-6 Production Facility(COGCC#438056) Enclosed Combustion Device(ECD)Emission Calculations for Truck Loadout Emission Source: Truck Loadout Source Type: ECD Heat Input: 0.04 MMBtu/hr Gas Oil Ratio(GOR): 1.79 scf/bbl Tank Vent Gas Flowrate: 13.4 scf/hr Tank Vent Gas Flowrate: 0.12 MMscf/yr Estimated HHV: 2,884 Btu/scf Sulfur Content of Fuel: 0.0020 gr/scf Operating Hours per Year: 8,760 hr/yr Emission Factors or Emissions Pollutant Uncontrolled Emissions(a) Ibihr(b)'(c) tpy(°) COP) 116.981b/MMBtu 4.537 19.873 N2O 0.00022 lb/MMBtu 0.000 0.000 NOx 0.068 lb/MMBtu 0.003 0.012 CO 0.3101b/MMBtu 0.012 0.053 SO2 0.00020 lb/MMBtu 0.000 0.000 PM10 40.0 pg/1 0.000 0.002 PMZ_5 40.0 Ng/I 0.000 0.002 Notes: (a)Emission factors are from AP-42 Tables 13.5-1&2(Industrial Flares) 40 pg/L is for lightly smoking flare(this is conservative as this unit is smokeless in design). SO2 emissions based on AP42,which is based on 100%conversion of sulfur to SO 2 at 2000 grains/MMscf. N2O emission factor from 40 CFR Part 98 Table C-2 for Natural Gas. (b)Hourly Emission Rate(lb/hr)except for PM,o=(Emission Factor,Ib/MMBtu)*(Heat Input,MMBtu/hr) (c)lb PM10/hr=(scf CH4/hr)(10.6 scf E/scf CH4)(0.0283 m3/scf E)(40 p PM10/L E)(1000 I/m')(9/106 pg)(lb/453.59 g)/(hr/yr) (d)Annual Emission Rate(tpy)=(Hourly Emission Rate,Ib/hr)*(hr/yr)/(2,000 lb/ton) (e)This represents CO2 as a product of combustion. It is calculated using equation W-21 of 40 CFR Part 98 • Bonanza Creek Energy Operating Company,LLC.-State Seventy Holes 21-6 Production Facility(COGCC 6438056) Condensate Tank Site Specific Emission Factor Calculations Emission Source: Condensate Tanks Designed Throughput: 180 bbl/day Designed Throughput: 65,700 bbl/yr Requested Throughput: 6.5.700 bbl/yr Enclosed Flare VOC Control Efficiency: 95% Operating Days per Year: 365 days/yr Total Emissions Emission Factors(') Actual Emissions(tpy)(°I Requested Emissions(tpy)(`) Pollutant (lb/bbl) Uncontrolled Controlled - Uncontrolled I Controlled CO2 0.0345 1.13 1.13 1.13 1.13 Methane 0.0707 2.32 0.12 2.33 0.12 VOC __.., 6.3425 208.36 1042 208.36 10.42 Benzene 0.0510 1.675 0.084 1.676 0.084 Toluene 0.0445 1.462 0.074 1.462 0.074 Ethylbenzene 0.0059 0.194 0.010 0.194 0.010 Xylenes 0.0143 0.470 0.024 0.470 0.024 n-Hexane 0.3458 11.360 I 0.568 11.360 0.569 224-TMP 0.0321 1.054 0.053 1.055 ! 0.053 Notes: - (a)Emission Factors from Permit 15N1E0383 Issuance 3. (c)Requested Emissions(tpy)_(Actual Emissions.tpy) (d)Uncontrolled Emissions goy)_(Emission Factor,Ib/bbt)•(Actual Throughput,bbpyr)/(2.000 Ibtton) Bonanza Creek Energy Operating Company,LLC.-State Seventy Holes 21-6 Production Facility(COGCC 66438056) Enclosed Combustion Device(ECD)Emission Calculations for Condensate Tank Battery 1 Emission Source: Condensate Tanks Source Type: ECD Heat Input Requested: 1.21 MMBtu/hr Heat Input Actual: 1.21 MMBtu/hr Gas Oil Ratio(GOR): 47.87 scf/bbl Tank Vent Gas Flowrate Requested: 359.0 scf/hr Tank Vent Gas Flowrate Requested: 3.15 MMscf/yr Tank Vent Gas Flowrate Actual: 359.0 scf/hr Tank Vent Gas Flowrate Actual: 3.15 MMscf/yr Pilot Gas Flowrate 16.8 scf/hr Pilot Gas Flowrate 0.15 MMscf/yr Combustors On Site 4 Total Flowrate to Combustor Including Pilot 3.73 MMscf/yr Estimated HI-IV: 2,838 Btu/scf Total VOC Control Efficiency: 95% Sulfur Content of Fuel: 0.0020 gr/scf Operating Hours per Year: 8.760 hrtyr Emission Factors or Actual Emissions Requested Emissions Pollutant Uncontrolled Emissions(') Iblhr(a.1`1 tpy"II Ib/hr l01 I tpy(°) CO2 116.98 Ib/MMBtu 141.51 619.81 141.51 619.81 N20 0.00030 lb/MMBtu 0.00 0.01 0.00 0.01 NOx 0.068lb/MMBtu 0.08 0.37 0.08 0.37 CO 0.3101b/MMBtu 0.38 1.65 0.38 1.65 SO2 0.00030 lb/MMBtu 0.0004 j 0.0016 0.0004 0.0016 PM1c 40.0 P9/1 0.0099 '0.0436 0.0099 0.0436 PMZ,5 40.0 N9 if 0.0099 0.0436 0.0099 0.0436 Notes (a)Emission factors are from AP-42 Tables 13.5-1&2(Industrial Flares) 40 pg/L is for lightly smoking flare(this is conservative as this unit is smokeless in design). SO;emissions based on AP42.which is based en 100%conversion of sulfur to 5O at 2000 grains/MMscf. C02 and N20 emission factors from 40 CFR Part 98 Table C-t and C-2 for Natural Gas. (b)Hourly Emission Rate(Ibihr)except for PM,,_(Emission Factor,IbiMMatu)-(Heat input.MM6lu(hr) (c)(scf CH.,/hr)(10.6 sot E/sct CH,)(0.0283 m'iscf E)(40 p PM,v'L E)(1000 Um')(g/100 pg)(lb/453.59 g)/Mr/yr)=b PM,,/hr (di Annual Emission Rate(tpy)_(Hourty Emission Rate.lb/hr)-(hr/yq!(2.000 lb/ton) Bonanza Creek Energy Operating Company,LLC.-State Seventy Holes 21.6 Production Facility(COGCC#438056) Pneumatic Device Emissions Calculations Pneumatic Devices Source Type: Pneumatic Devices Device Count* Device Bleed Rate Positioners 1 2.100 scf/hr per device Gas Lift/Booster Engine Liquid Level Controllers 5 6.000 scf/hr per device Produced Water Vault Liquid Level Controllers 2 0.800 scf/hr per device All Other Liquid Level Controllers 16 0.800 scf/hr per device Temperature Controllers 6 0.800 scf/hr per device Total 30 51.300 scf/hr Gas Molecular Weight t`I 23.8 lb/lb-mole Total Bleed Rate: 0.4 MMscf/yr Operating Hours per Year: 8,760 hr/yr Emissions Rate Uncontrolled Uncontrolled Uncontrolled Uncontrolled Uncontrolled Uncontrolled Emission Gas Composition Factor iv Per Positioner Per Gas Lift/Booster LLC Per PW Vault LLC Per Other LLC Per TC Total for All Devices Pollutant Wt%(el (lb/MMscf) lb/hr 1°i tpy f°) lb/hr(v) tpy Ihi Ib/hr(li) tpy I° lb/hr 191 tpy(h) tb/hr 19) tpy III lb/hr t9) tpy(°I COZ'e j j j 3.82 2,400.2 0.01 0.02 0.01 0.06 000 j 0.01 0.00 0.01 0.00 j 0.01 0 12 0.54 Methane 46.31 29,078 6 0.06 0.27 0.17 , 0.76 0.02 0.10 0.02 0.10 0.02 0.10 1 49 6 53 VOC 30.95 19,434.47 0.04 0.18 0.12 0.51 0.02 I 0.07 0.02 0.07 0.02 0.07 1 00 4.37 Benzene 0.07 45.38 0.000 I 0.000 0.000 J 0.001 0 000 j 0.000 0.000 0.000 0.000 0.000 0.002 0.010 Toluene 0.09 55.23 0.000 0.001 0.000 0001 0.000 I: 0.000 0.000 0.000 0.000 0.000 -0003 0.012 Ethylbenzene 0.03 20.84 0.000 0.000 0.000 • 0.001 0.000 I 0.000 0.000 0.000 0.000 0.000 0.001 0.005 Xylenes 006 39.38 0.000 0,000 0.000 i 0001 0.000 1 0.000 0.000 0 000 0.000 0.000 0.002 7 0009 -I n-Hexane 0.53 331.13 0.001 0.003 0.002 0.009 0.000 I 0.001 0.000 0.001 0.000 0.001 0.017 0,074 2,2,4-Trimethylpentane 0.07 46.43 0.000 j 0.000 0.000 ; 0.001 0.000 i 0.000 0 000 0.000 0.000 0.000 0.002 0.010 Notes (a)Based on a representative device count per piece of equipment (b)Based the manufacturer provided bleed rate for typical devices used (c)Based en Colorado Regulation 7 requirement that pneumatic conloters must have a natural gas bleed rate less than or equal to 6.0 scfav (d)Bleed rate front Table 2 in the ACS Publication"Methane Emissions horn Process Equipment at Natural Gas Production Sites in the United States:Pneumatic Controllers' (e)Gas molecular weight and constituent weight percentages based on weighted average sales gas analysis (t)Emission Factor(Its/MMscl)_(MW,Ibab-mole)1(379 sctab-mole)•Iconsituent weight%)1 100-lee (g)Hourly Emission Rate(lb/hr)=(Pump Rate,SCFH)•(MW,Ibab-mot)11379 scf/lb-mole)•(WI%) (h)Annual Emission Rate(tpy)_(Hourly Emission Rate.lb/hr)•(hr/yr)1(2.000 lb/ton) Ii)This represents CO2 existing in the fuel gas(uncombusted) A cDPHE COLORADO Form APCD-101 Co Department of Public Health & Environment Company Contact Information Form Ver.September 10,2008 Company Name: Bonanza Creek Energy Operating Company, LLC (BCEOC) Source Name: State Seventy Holes 21-6 Production Facility (COGCC#438056) Permit Alisson Soehner Compliance Matt Cannizzaro Contact': Contact 410 17th Street, Suite 1400 410 17th Street, Suite 1400 Address: Street Address: Street Denver CO 80202 Denver CO 80202 City State Zip City State Zip Phone Number: (303) 803-1752 Phone Number: (303) 803-1752 Fax Number: (720) 305-0804 Fax Number: (720) 305-0804 E-mail: asoehner@bonanzacrk.com E-mail: mcannizzaro@bonanzacrk.com Billing Contact: Alisson Soehner Billing Contact: Alisson Soehner (Permit Fees? (Annual Fees' 410 17th Street, Suite 1400 410 17th Street, Suite 1400 Address: Street Address: Street Denver CO 80202 Denver CO 80202 City State Zip City State Zip Phone Number: (303) 803-1752 Phone Number: (303) 803-1752 Fax Number: (720) 305-0804 Fax Number: (720) 305-0804 E-mail: asoehner@bonanzacrk.com E-mail: asoehner@bonanzacrk.com Check how would you like to receive your permit fee invoice? Mail: a E-mail: fl Fax: F-1 Footnotes: The permit contact should be the point of contact for technical information contained in the permit application. This may be a company representative or a consultant. 2 The compliance contact should be the point of contact for discussing inspection and compliance at the permitted facility. 3 The billing contact(Permit fees)should be the point of contact that should receive the invoice for fees associated with processing the permit application&issuing the permit.(Reg. 3, Part A, Section VI.B) The billing contact(Annual fees)should be the point of contact that should receive the invoices issued on an annual basis for fees associated with actual emissions reported on APENs for the facility. (Reg. 3, Part A, Section VI.C) Page 1 of 1 AP_Form-APCD-1 0 1-Company-Contact-Information(2).doc • • Colorado Department of Public Health and Environment Form APCD-102 Air Pollution Control Division A C D P H E 06 Facility Wide Emissions Inventory Form Ver.Apnl.2(115 CO Company Name:Bonanza Creek Emery Operating Comports.LL(' 0 Source Name:State Seventy Holes 2I-b Production Facdm(COGCC f43Rn5v) 7I^ Source AIRS ID:I23-9D32 t nemlmded 15nm0.1 to Emil IN E1 l'onoulled Pnim0.1 In Lull 11'I II tnleria(IP11 I 11A15(IW3r) Arne.(IPA) 11Alt ltbrhr) 1 Al.111 Equip..Deacript. 'I EP .110 1'312-5 .tint NO% VOA AO 1114'11(1 Arno! Au. Ni TO EH X11 n-Ilea Ak& 221-T51P ISP 1•\110 P512.5 102 Nn1 Vnm' 1(1 110111 A.e1.t Aln. 11% FA EH 5)1 n-Ilex 51.91 224-TNIP 127!111124112 0,18101,404 tank 118nn+I - - - - 208;1 - I - - - 620.~3.544 1%9 I 15.114 - 110 1111 0(I 04 1114 57 - - - 2011 227 10 I 1.707 - u 121!1)112411) )':010005 N anti Tank I _ _ _ _ ., _ I _ _ _ 1or 0 1 •(.1 - (1 _ _ _ _ 0 V _ _ _ _ 10 n II - I25AH124109 I.,n P,om,e lin.Hanna - - - - 47,5 - I - - - 2955 1496 114 1464 71.1114 - 24413 (12 112 110 1121% 45 - - - 150 I'f. 42 74 1,052 - 14% I21-71)32-0, !suck 1,03011 0 II 11 0 110 II 0 04 111 - - - 0 254 - 1 .1 11.911125110 0010171F E II'n.l: 0-.A 111 011 4,11 21. 224 I 5'2 ',5 71 II II 11 5 , - 01 111 110 47 2t. 1 552 75 71 JI II I 5 - Il - 1 , 1.00111 Mntrcen En..0 0.0 0.3 0.3 0.0 47.0 700.0 224 I 552 75 71 9.193 8,055 1.413 1470 62,964 62 2,940 0.0 0.5 0.5 CO Si 37.4 13.9 I 552 75 71 503 all 73 79 3.15} 02 116 WEN Ihk-lintel 1:3rapl Munn I I I I ,1PEN(Ink Nub.,,.- 0.0 0.0 00 00 0.0 0.0 00 I n 0 on a a a 0 n a 0.0 BA mu 0.0 0.0 0.0 9.o I a 0 0 0 0 0 0 0 0 0 AI•E5 l:lentpr/Inninriikml.u9rcn - _. -.... ... -. r _. - _ 1 .. 1'11,400.3 Wank V4uil, _ _ _ _ _ _ _ _ 0 0 0 , -- 0 _ - _ - _ t _ _ _ 257. 00 00 00 I. 807 - 100 11,7074,04,5100. 72 02 011 23 01 1'1 1 - - 0 - - 75 -- - 112 01 Ill 2.7 III 14 I I.1 - - 0I 111 - - 14.3 - - Pn.uo,.c tb,ion,I - - - - 4 4 - - - , - 20 25 9 I8 149 - 21 U1 2 . - - - 4 4 - I - - , - 204 24 1 '(4 17 7 148% - 209 174710.7 1750070701046 _ -- - - - 114 - - - - 22 45 III 42. 11.5 - 72 0.2 - - - 04 - L - - - 22 I6 I0 12 155 - 12 170,0.7.0111005000 - - 02 - - - - I I I I x - I - - - 02 - I - - - I 1 1 .. 1 . 4 - 1 I Inwp•iliie.nl NUM1m1.l> 0.0 0.2 0.2 0.0 2.3 5.6 1.9 3 0 0 49 41 II 23 327 0 25 le 0.6 11.] O.e 2.3 5.6 1.9 I 3 0 0 19 II II 23 - 337 0 25 - 1.04,Ill'"..A 0.0 1 0.1 1 0.1 I 0.0 1 453 i ies.6 I 24.4 0 555 I 75 I 11 19.242 1 a,006I 1,424 1 1,493 163,291 I 02 1 2,974 I 0.11 I 1.1 1 0.7 1 0.0 1 7.4 I 43.0 I 15.11 1 555 1 75 1 -1 I 552 1 449 1 04 1 102 1 3.1001 02 I 1-3 Pmmm.0e011VS Sunm,n(1 PI,-I 03 1 0.11 10.0 I 4.6 1 411 I 0.7 1 07 I 31.6 1 II. I 1E I l'onkdkd 11.71'.Summary(17•I4 OS I 0.0 1 lu 10.3 I 0.2 1 to 10.1 I 1.7 1 0.0 I 0.1 I n-atr.0led'1851,All 11.5151liE)=MI 1'„ntniini lm.1,All ILA15 all 2.0 Footnotes: I Pus form should be completed to include both a-isfng sources and all proposed nest or modifications to esishng 011055103 50110005 2 If the',comm..source is noes then enter"proposed"under the Perron No.and AIRS It)data columns s. HAP abbresaauuns include. - BA=Benzene 221-TMP=22.4-Tnmcihc Ipentanc Tol=Toluene Metal-Acelaldohcde EB-Elhylbenzene Aeon-Actoloin Xyl=Xc lone n-lieu=n-Hc.sano IIC11O=Formaldeh,de Meth=Methanol 4 APES ExempPlnsignlficont Sources should be included when warranted Condensate Storage Tank(s) APEN 0 `'Y,a Form APCD-205 CDPHE Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. Incomplete APENs will be rejected and will require re-submittal. Your APEN will be rejected if it is filled out incorrectly, is missing information, or lacks payment for the filing fee. The re-submittal will require payment for a new filing fee. This APEN is to be used for tanks that store condensate associated with oil and gas industry operations. If your emission source does not fall into this category, there may be a more specific APEN available for your source(e.g. crude oil storage tanks, produced water storage tanks, hydrocarbon liquid loading, etc.). In addition, the General APEN (Form APCD-200)is available if the specialty APEN options will not satisfy your reporting needs. A list of all available APEN forms and associated addendum forms can be found on the Air Pollution Control Division (APCD) website. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment,change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: 15WE0363 AIRS ID Number: 123 / 9D32 /012 Section 1 - Administrative Information Company Name': Bonanza Creek Energy Operating Company.LLC(BCEOC) Site Name: State Seventy Holes 21-6 Production Facility(COGCC#438056) Site location: Site Location 40.34681, -104.3741 County: Weld Lot 2, 4N, 6, 62W NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E-Mail Address2: asoehner@bonanzacrk.com 1 Use the full, legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. 2 Permits,exemption letters,and any processing invoices will be issued by the APCD via e-mail to the address provided. 431103 illiMCOLORADO NW1A6 G�rmnonl Permit Number: 15WE0363 AIRS ID Number:. 123 I 9D32/012 Section 2 - Requested Action O NEW permit OR newly-reported emission source ❑ Request coverage under traditional construction permit o Request coverage under a General Permit O GP01 ❑ GP08 If General Permit coverage is requested, the General Permit registration fee of$312.50 must be submitted along with the APEN filing fee. -OR- [3 MODIFICATION to existing permit(check each box below that applies) ❑ Change in equipment O Change company name3 (] Change permit limit ❑ Transfer of ownership4 El Other(describe below) -OR- ❑ APEN submittal for update only(Note blank APENs wilt not be accepted) -ADDITIONAL PERMIT ACTIONS- • APEN submittal for permit exempt/grandfathered source ❑ Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) Additional Info& Notes: Requesting new throughput and emission limits using previously established emission factors. 3 For company name change,a completed Company Name Change Certification Form (Form APCD-106)must be submitted. 4 For transfer of ownership, a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: Condensate storage tank battery used to store condensate Company equipment Identification No. (optional): CNDTK-01 For existing sources, operation began on: 11/22/2014 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Storage tank(s) located at: Q Exploration&Production(EEP)site ❑ Midstream or Downstream (non E&P)site Will this equipment be operated in any NAAQS nonattainment area? 0 Yes ❑ No Are Flash Emissions anticipated from these storage tanks? ❑� Yes O No Is the actual annual average hydrocarbon liquid throughput≥ 500 bbl/day? O Yes No If"yes", identify the stock tank gas-to-oil ratio: m3/liter Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) ❑ Yes / No 805 series rules?If so, submit Form APCD-105. Are you requesting≥6 ton/yr VOC emissions(per storage tank), or are uncontrolled actual ❑ Yes No emissions≥6 ton/yr(per storage tank)? Age COLORA00 Permit Number: 15WE0363 AIRS ID Number: 123 /9D32/012 Section 4 - Storage Tank(s) Information Actual Annual Amount Requested Annual Permit Limits (bbl/year) (bbl/year) Condensate Throughput: I 65,700 65,700 From what year is the actual annual amount? 2019 Average API gravity of sales oil: 40.1 degrees RVP of sates oil: 8 Tank design: ✓❑ Fixed roof ❑ Internal floating roof ❑External floating roof Storage #of Liquid Manifold Storage Total Volume of Installation Date of Most Date of First Tank ID Vessels in Storage Tank Storage Tank Recent Storage Vessel in Production (bbl) Storage Tank(month/year) (month/year) CNDTK 01-10 Ten(10)500 bbl 5,000 8/2014 11/2014 Wells Serviced by this Storage Tank or Tank Battery6(E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 • 39860 State Seventy Holes 11-14-6HNB 0 05 • 123 - 39859 State Seventy Holes A11-E14-6HNC 0 05 - 123 - 39858 State Seventy Holes A-E-6HNB 0 05 - 123 - 39861 State Seventy Holes F11-J14-6HNC ❑ 05 - 123 - 39862 State Seventy Holes F-J-6HNB 0 s Requested values will become permit limitations or will be evaluated for exempt status,as applicable,and should consider future process growth. Requested values are required on all APENs,including APEN updates. 6 The E&P Storage Tank APEN Addendum(Form APCD-212)should be completed and attached when additional space is needed to report all wells that are serviced by the equipment reported on this APEN form. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.34681,-104.3741 0 Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Operator Stack Discharge Height Above Temp. Flow Rate Velocity ID No. Ground Level(Feet) (°F) (ACFM) (ft/sec) ECD 01-04 —25 I 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑Downward 0 Upward with obstructing raincap ❑Horizontal 0 Other(describe): Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter(inches): 48 ❑Square/rectangle Interior stack width(inches): Interior stack depth(inches): ❑Other(describe): COLORADO 'XWtIf 6lnv,ronment Permit Number: 15WE0363 AIRS ID Nurriber: 123 /9D32/012 Section 6 - Control Device Information ❑ Check this box if no emission control equipment or practices are used to reduce emissions, and skip to the next section. • Pollutants Controlled: Vapor Size: Make/Model: ❑ Recovery Unit (VRU): Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Pollutants Controlled: VOC, HAPs Rating: 1.21 MMBtu/hr Type: Enclosed Combustor Make/Model: Four(4) LEED L30-0011 0 Combustion Requested Control Efficiency: 95 % Device: Manufacturer Guaranteed Control Efficiency: 98 Minimum Temperature: 500 Waste Gas Heat Content: 2,838 Btu/scf Constant Pilot Light: Yes 0 No Pilot Burner Rating: 0.19 MMBtu/hr Description of the closed loop system: ❑ Closed Loop System Pollutants Controlled: 0 Other: Description: Control Efficiency Requested: Section 7 - Gas/Liquids Separation Technology Information (EEtP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? —50 psig Describe the separation process between the well and the storage tanks: Gas and oil produce to high/low pressure separators where liquids are separated from the natural gas in the high pressure side of the separator. The liquids are then sent to the low pressure separator where oil and water are separated and oil is sent to the tank battery. GOLORAOO Permit Number: 15WE0363 AIRS ID Number: 123 /9D32/012 Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form'. Is any emission control equipment or practice used to reduce emissions? 0 Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or combined, values if multiple emission control methods were identified in Section 6): Collection Efficiency Control Efficiency Pollutant Control Equipment Description (%of total emissions captured (%reduction of captured by control equipment) emissions) V0C ECD 100 95 NOx CO _ HAPs ECD 100 95 Other: From what year is the following reported actual annual emissions data? 201 9 Use the following table to report the criteria pollutant emissions from source: Requested Annual Permit Emission Factor' Actual Annual Emissions Emission Limit(s)5 Pollutant Source Uncontrolled Controlled Uncontrolled Controlled Uncontrolled Units (�2 Emissions Emissions Emissions Emissions Basis Mfg.,etc.) (tons/year) (tons/year) (tons/year) (tons/year) VOC 6.3435 Ib/bbl Permit 13 208.36 10.42 208.36 10.42 NOx 0.068 Ib/MMBtu AP-42 0.37 0,37 0.37 0,37 CO 0.310 Ib/MMBtu AP-42 1.65 1.65 1.65 1.65 5 Requested values will become permit limitations or will be evaluated for exempt status,as applicable, and should consider future process growth. Requested values are required on all APENs,including APEN updates. 'Attach condensate liquid laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. Section 9 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria 0 Yes O No pollutants(e.g. HAP- hazardous air pollutant)equal to or greater than 250 lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Chemical Emission Factor' Actual Annual Emissions Abstract Source Uncontrolled Controlled Chemical Name Service(CAS) Uncontrolled Units (AP-42, Emissions Emissions8 Number Basis Mfg.,etc.) (lbs/ ear y ) (lbs/year) Benzene 71432 0.051 Ib/bbl Permit 13 3.351 168 Toluene 108883 0 0445 Ib/bbl Permit 13 2.924 148 Ethylbenzene 100414 0.0059 Ib/bbl Permit 13 388 20 Xylene 1330207 0.0143 Ib/bbl Permit 13 940 48 n-Hexane 110543 0.3458 Ib/bbl Permit l3 22.720 1136 2,2,4-Trimethylpentane 540841 0.0321 lb/bbl Permit 13 2.109 106 'Attach condensate liquid laboratory analysis,stack test results,and associated emissions calculations if you are requesting site specific emissions factors according to the guidance in PS Memo 14-03. 8 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,provide projected emissions. COLORADO rn.p.n.,.,na we,r A b Enr„mmen, Permit Number: 15WE0363 AIRS ID Number: 123 /9D32/012 Section 10 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. If this is a registration for coverage under General Permit GP01 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 5/4/2020 Signature of Legally Authorized Person (not a vendor or consultant) Date Alisson Soehner Environmental Engineer,Air Quality Name (print) Title sill Check the appropriate box to request a copy of the: 0 Draft permit prior to issuance D Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made(significant emissions increase, increase production, new equipment, change in fuel type, etc.). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with $191.13 and the General Permit For more information or assistance call: registration fee of$312.50, if applicable, to: Small Business Assistance Program Colorado Department of Public Health and Environment (303)692-3175 Air Pollution Control Division OR APCD-SS-B1 (303)692-3148 4300 Cherry Creek Drive South Denver, CO 80246-1530 APCD Main Phone Number (303)692-3150 Make check payable to: Colorado Department of Public Health and Environment COLORADO Deav se a nmr turm a u.uo.m+m BOf Rn z R CREEK Process Description State Seventy Holes 21-6 Oil & Gas Production Facility The State Seventy Holes 21-6 Production Facility(COGCC#438056) is an oil and gas production facility located within the eight-hour(8-hr)Ozone Control Area of Weld County. The facility produces both oil and natural gas from five(5)wells, The facility is currently authorized to operate the following equipment: • One(1) Cummins KTA19GC Natural Gas Engine; • Ten (10) Condensate Oil Tanks(10 @ 500 bbl); • Two(2) Produced Water Tanks(2 @ 500 bbl); • Two(2)Concrete Water Vaults (2 @ 60 bbl); • Five(5) Separator Burners(4 @ 1.15 MMBtu/hr capacity, 1 @ 0.75 MMBtu/hr capacity); • Four(4)Leed Fabrication L30-0011 48" ECDs; • Five(5) High/Low Pressure Separators; • Pneumatic Devices; • Compressor Blowdown; • Hydrocarbon Truck Loading Operation; and • Fugitive Equipment Leaks. Gas and oil produced from the wells is processed through a high pressure separator where liquids are separated from the natural gas. The overhead gas from the high pressure side of the separator burner is sent to a gathering pipeline. The liquids are then sent to the low pressure separators where the oil and water are further separated.The water and oil are sent to their respective storage tanks before being trucked from the facility. Truck loading vapors are returned to the condensate tanks via vapor return lines and then sent to the enclosed flares for control. The overhead gas from the low pressure separators is routed to the existing enclosed combustors. Flashing, working and breathing loss vapors from the oil tanks and water tanks are routed to the enclosed combustors. The enclosed combustors have a vendor guaranteed destruction efficiency of 98% or higher, with an overall net control efficiency of 95%. The gas compressors for gas lift and boost to gathering line pressure are driven by the Cummins KTA19GC natural gas fired RICE. Finally, each separator burner, fugitive emission, concrete water vault, compressor blowdown, and pneumatic device is an APEN-exempt emission source having less than 2 tons per year of any single pollutant and/or 1 tons per year of VOC and NOx(the facility is located within the nonattainment 8-hour Ozone Control Area). � a i f ti o 11,. lrl 11:forage j ... tangs 10-S00iab, ILT i Oil Truck toadout • High/law Pressure Separators i (, SEP-0I-SEP-0S d: Horizontal Wells t fW'fa-k Water Trucked Out State Seventy Holes 21-6 Production Facility B 0!1 A A Z A Lot 2,T4N,R62W,Sec 6 CREEK Weld County,Colorado Cr.r. COLORADO Form APCD-304 Air Pollution Control Division APCD Internal Use Only CDPHE Department of Public Health b Environment Received Date Approved? ❑ Approval Date Operating and Maintenance Plan Template for Condensate Storage Tanks Ver. January 27, 2020 The Air Pollution Control Division developed this Operating and Maintenance Plan (O&M Plan) for condensate storage tanks that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. One O&M Plan may be used for multiple tanks at one facility if each are controlled and monitored in the same manner. An O&M Plan shall be submitted with the permit application when required. The facility operator must comply with the requirements of the O&M Plan upon commencement of operation. An existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved O&M Plan until an approval letter is issued for the new O&M Plan. The operator is required to use the division-developed O&M Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or emissions unit is subject to other state or federal regulations with duplicative requirements, the operator must follow the most stringent regulatory requirement. Please note that O&M requirements are different for facilities in the Denver Metro and North Front Range 8-hour ozone nonattainment area. For sources that are subject to the Title V Operating Permits program: In accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this O&M plan will be incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring not listed in this O&M Plan may be included in the source's Operating Permit in order to satisfy the periodic monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b. Submittal Date: May 2020 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: Bonanza Creek Energy Facility 40.34681,-104.3714 Operating Company,LLC Location: Lot 2,4N,6,62W (BCEOC) Facility Name: State Seventy Holes 21-6 Facility AIRS ID (for existing facilities) 123 - 9D32 Production Facility(COGCC #438056) Is this facility located in the Denver ® Yes Metro and North Front Range 8-hour ❑ No ozone nonattainment area? Emission Units Covered by this O&M form Facility Equipment ID CNDTK-01 Permit Number 15WE0363 AIRS Point ID 012 Page 1 of 4 l+.~iM COLORADO Air Pollution Control Division CDPHE Department of Public Health&Environment Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions (l unit and control devices. These schedules and practices, as well as all maintenance records showing compliance with these recommendations, shall be made available to the division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of emissions unit and control devices. These schedules and practices, as well as all ® maintenance records showing adherence to these practices, shall be made available to the division upon request and shall be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. I Section 3 - Recordkeeping Requirements The following box must be checked for the O&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for ® the requirements of this O&M Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period,the operator must comply with the longest record retention requirement. Section 4 - Monitoring Requirements Check one of the following two boxes: Check this box to confirm that the storage tank(s) are subject to the requirements of Regulation No. 7, Sections XVII.C.2. and C.3 (Storage Tank Emission Management System "STEM"). By checking this ® box, the operator confirms adherence to the operating, maintenance, and recordkeeping requirements of STEM as developed and implemented by the operator, as required by Regulation No. 7, Sections XVII.C.2. and C.3. Check this box if the storage tank(s) are not subject to the requirements of Regulation No. 7, Sections XVII.C.2. and C.3. ("STEM"). Leakage to the atmosphere shall be minimized as follows: • Thief hatch seals shall be inspected monthly for integrity and replaced as necessary; • Thief hatch covers shall be properly weighted and seated to ensure flashing,working, and breathing losses (as applicable) are routed to the control device under normal operating conditions; • Pressure relief valves (PRY) shall be inspected monthly for proper operation and repaired or replaced as necessary; • PRVs shall be set to release at a pressure that will ensure flashing, working, and breathing losses (as applicable) are routed to the control device under normal operating conditions; and • Inspections shall be documented with an indication of status, a description of any problems found, and their resolution (e.g., adjustments made to thief hatch weight cover weight or PRV setpoint, including the modified settings). Page 2 of 4 C.. r: :i COLORADO Air Pollution Control Division CDPHE Department of Public Health&Environment Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the storage tank emissions control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency" based on the facility attainment area status and facility-wide permitted VOC emissions. Table 1 Monitoring Frequency Ozone Nonattainment Area Ozone Attainment Areas Emissions Control or Parameter n Permitted ® Permitted n Permitted n Permitted Recycling Method Facility Facility Facility Facility Emissions Emissions Emissions Emissions t 40 tpy VOC < 40 tpy VOC a 80 tpy VOC < 80 tpy VOC Pilot Light/Auto- Enclosed Flare igniter Monitoring or Elevated ® and Daily b,C Weekly b'c Daily b,° Weekly b' Open Flare a Visible Emissions Observation Vapor Recovery Unit(VRU)or Monitoring requirements, including parameters and frequency, to be determined by the Recycled or ❑ operator and listed below in footnote d. Closed Loop System d Other n Monitoring requirements, including specific parameters and frequency, to be described in Section 5 below, and approved by the division. a Elevated Open Flare If the storage tank is subject to Regulation No. 7, Section XII or Section XVII, the use of an open flare must be approved by the division as an alternate emission control device prior to operation in accordance with Regulation No. 7 Section XVII.B.2.e.; see PS Memo 15-03. Open flares permitted prior to May 1, 2014 are approved for operation. All new open flares permitted on or after May 1, 2014 are required to obtain division approval prior to operation. b Pilot Light Monitoring Options If the tanks are controlled by combustion device, then the operator must indicate in Table 2 the primary method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, secondary methods may be checked. Table 2: Pilot Light Monitoring Primary Secondary Monitoring Method ® ❑ Visual Inspection _ ❑ Optical Sensor ❑ ❑ Auto-Igniter Signal ❑ Thermocouple Page 3 of 4 MlM1M COLORADO Air Pollution Control Division CDPHE Department of Public Health&Environment Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1,the operator is required to conduct an inspection of the subject combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection, the operator has the option to either (1) immediately shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.17.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this O8M Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific repairs completed. If the emissions unit is subject to Regulation No. 7, Section XII.E, operators must document the required inspections for the presence or absence of smoke. The division has historically approved a"check box"to satisfy the documentation procedures referenced in Section XII. The division will continue to accept the "check box" recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance with Regulation No. 7 Section XII.E.4.a. d Vapor Recovery Unit (VRU)or Recycled or Closed Loop System In the space provided below,please provide a description of the emission control or recycling system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times,or during all permitted runtime. Also,provide a description of how downtime is tracked and recorded. N/A Section 5 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. N/A Page 4 of 4 Form APCD-312 • �;�:_� COLORADO APCD Internal Use Only Air Pollution Control Division Received Date CDPHE o. Department of Public Health&Environment Approved? ❑ Approval Date Operating and Maintenance Plan Template for Hydrocarbon Liquid Loadout Ver. January 27, 2020 The Air Pollution Control Division developed this Operating and Maintenance Plan (OEM Plan) for hydrocarbon liquid loadout activities that use emissions controls, permitted at synthetic minor and major oil and gas facilities in the State of Colorado. One OEM Plan may be used for multiple loadouts at one facility if each are controlled and monitored in the same manner. An O&M Plan shall be submitted with the permit application when required. The facility operator must comply with the requirements of the O&M Plan upon commencement of operation. An existing approved O&M Plan may be modified without a permit modification or permit reissuance, but the operator must adhere to the requirements of the existing approved OEM Plan until an approval letter is issued for the new OEM Plan. The operator is required to use the division-developed O&M Plan template forms in order to meet minimum expectations within a standard, organized format. Do not modify the structure and/or content of this template. If the facility or emissions unit is subject to other state or federal regulations with duplicative requirements, the operator must follow the most stringent regulatory requirement. Please note that O&M requirements are different for facilities in the Denver Metro and North Front Range 8-hour ozone nonattainment area. For sources that are subject to the Title V Operating Permits program: In accordance with Colorado Regulation No. 3, Part C, Section V.C.5., some or all of the monitoring specified in this O&M plan wilt be incorporated as specific conditions in the source's Title V Operating Permit (if applicable). Additional monitoring not listed in this O&M Plan may be included in the source's Operating Permit in order to satisfy the periodic monitoring requirements of Regulation No. 3, Part C, Section V.C.5.b. Submittal Date: May 2020 Section 1 - Source Identification For new permits, some of this information (i.e., Facility AIRS ID, Permit Number, and AIRS Point ID) may not be known at the time of application. Please only fill in the fields that are known and leave the others blank. Company Name: Bonanza Creek Energy Facility Location: 40.34681, -104.3714 Operating Company,LLC Lot 2, 4N, 6, 62W (BCEOC) Facility Name: State Seventy Holes 21-6 Facility AIRS ID (for existing facilities) 123 - 9D32 Production Facility (COGCC #438056) Is this facility located in the Denver ® Yes Metro and North Front Range 8-hour ❑ No ozone nonattainment area? Loadout Sources Covered by this OEM form Facility Equipment ID L-01 Permit Number 15WE0363 Page 1 of 4 COLORADO iAir Pollution Control Division CDPHE Department of Public Health 8 Environment I AIRS Point ID I 010 Section 2 - Maintenance Schedules Check one of the following: Facility shall follow manufacturer recommendations for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all maintenance records showing compliance with these recommendations, shall be made available to the division upon request. Facility shall follow individually developed maintenance practices and schedules for the operation and maintenance of the emissions unit and control devices. These schedules and practices, as well as all ® maintenance records showing adherence to these practices, shall be made available to the division upon request and shall be consistent with good air pollution control practices for minimizing emissions as defined in the New Source Performance Standard (NSPS) general conditions. Section 3 - Recordkeeping Requirements The following box must be checked for the O&M Plan to be considered complete: Synthetic minor and major sources are required to maintain maintenance and monitoring records for ® the requirements of this OitM Plan for a period of five (5) years. If applicable state requirements or any Federal NSPS, NESHAP, or MACT require a longer record retention period, the operator must comply with the longest record retention requirement. Section 4 -Monitoring Requirements Control Equipment Information Check the appropriate box below that describes the technique used to collect truck loadout vapors. ® Vapor balance connects the truck vapor headspace to the storage tanks, and the displaced vapors are controlled along with storage tank vapors. Direct connection to combustion device, not via storage tanks. [] Other (describe in Section 5). Page 2 of 4 CAiii, Ml:4M COLORADO Air Pollution Control Division CDPHE Department of Public Health&Environment Table 1 below details the monitoring parameters and frequency for control equipment depending on the type of control equipment and the requested permitted emissions at the facility. Indicate the emissions control by checking the appropriate boxes. In addition, check the appropriate box for "Monitoring Frequency"based on the facility attainment area status and facility-wide permitted VOC emissions. Table 1 Monitoring Frequency Ozone Nonattainment Area Ozone Attainment Areas Emissions Control or Parameter n Permitted ® Permitted n Permitted n Permitted Recycling Method Facility Facility Facility Facility Emissions Emissions Emissions Emissions ≥ 40 tpy VOC < 40 tpy VOC ≥ 80 tpy VOC < 80 tpy VOC Pilot Light/Auto- Enclosed Flare igniter Monitoring or Elevated ® and Daily b'c Weekly b,c Daily b'` Weekly b, Open Flare a Visible Emissions Observation Vapor Recovery Unit(VRU)or Monitoring requirements, including parameters and frequency, to be determined by the Recycled or n operator and listed below in footnote d. Closed Loop System Other n Monitoring requirements, including specific parameters and frequency, to be described in Section 5 below, and approved by the division. a Elevated Open Flare An open flare permitted after May 1, 2014 and used to comply with Regulation No. 7 Section XVII must be approved by the division as an alternate emission control device prior to operation, in accordance with Regulation No. 7 Section XVII.B.2.e.; see PS Memo 15-03. b Pilot Light Monitoring Options If emissions are controlled by combustion device, then the operator must indicate in Table 2 the method by which the presence of a pilot light will be monitored. One primary method for Pilot Light Monitoring must be checked and, optionally, secondary methods may be checked. Table 2: Pilot Light Monitoring Primary Secondary Monitoring Method Z ❑ Visual Inspection — EDOptical Sensor n ❑ Auto-Igniter Signal ❑ ❑ Thermocouple Page 3 of 4 COLORADO Air Pollution Control Division COPHE Department of Public Health&Environment Visible Emissions Observation and Method 22 Options At the frequency specified in Table 1, the operator is required to conduct an inspection of the subject combustion device for the presence or absence of smoke (e.g., visible emissions). If smoke is observed during the visible emissions inspection the operator has the option to either (1) immediately shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (2) conduct a formal Method 22 observation to determine whether visible emissions (as defined per Regulation No. 7, Section XVII.A.17.) are present. If a Method 22 is conducted, the record of the observations shall be maintained as required in Section 3 of this OI*M Plan (Reference: Regulation No. 7, Section XVII.C.3.d). If visible emissions are observed by Method 22, the operator shall immediately conduct any necessary repairs and maintain records of the specific repairs completed; if repair cannot be immediately completed, the operator shall shut-in the emissions unit, conduct any necessary repairs, and maintain records of the specific repairs completed. If the emissions unit is subject to Regulation No. 7, Section XII.E, operators must document the required inspections for the presence or absence of smoke. The division has historically approved a"check box"to satisfy the documentation procedures referenced in Section XII. The division will continue to accept the "check box" recordkeeping format in instances where no visible emissions are observed in order to demonstrate compliance with Regulation No. 7 Section XII.E.4.a. If a flare is not subject to Regulation No. 7 requirements (as described in the permit), a similar approach may be employed where the operator may conduct an inspection for presence or absence of smoke, and if smoke is observed the operator has the option to (1) immediately conduct repairs and maintain records of the specific repairs completed; (2) shut-in the emissions unit to investigate the cause of the smoke, conduct any necessary repairs, and maintain records of the specific repairs completed; or (3) conduct a formal Method 9 observation to determine the opacity of the visible emissions, and conduct repairs if necessary. d Vapor Recovery Unit (VRU)or Recycled or Closed Loop System In the space provided below,please provide a description of the emission control or recycling system, including an explanation of parameters monitored, monitoring frequency, and how the system design ensures that emissions are being routed to the appropriate system at all times,or during ail permitted runtime.Also,provide a description of how downtime is tracked and recorded. N/A Section 5 - Additional Notes and O&M Activities Please use this section to describe any additional notes or operation and maintenance activities, or if additional space is needed from a previous section. Attach additional pages if necessary. N/A Page 4 of 4 ATTACHMENT I Regulatory Applicability Information This document provides regulatory applicability information to supplement the construction permit application for Bonanza Creek Energy Operating Company, LLC's State Seventy Holes 21-6 Production Facility. An analysis of the applicability of state and federal air quality permitting requirements and air pollution control regulations for the emissions sources is provided, along with an appropriate explanation and rationale regarding the applicability or non-applicability of specific regulations for the emissions sources. Regulation 3: Permitting and APEN Requirements Regulation 3, Part A, Section II: The produced water vaults, heated separators, pneumatic devices, fugitive equipment leaks, and compressor blowdown emissions are not subject to APEN reporting. Uncontrolled actual emissions of all criteria pollutants (except volatile organic compounds [VOC] and nitrogen oxides [NOx]) are less than 2 ton per year (tpy), and NOx and VOC emissions are less than 1 tpy within the nonattainment 8-hour Ozone Control Area [Regulation 3,Part A.II.B.3.a and Part A.II.D.1.a]. Regulation 3, Part B, Section II: The produced water vaults, heated separators, pneumatic devices, fugitive equipment leaks, and compressor blowdown emissions are not subject to permitting because they are not subject to APEN reporting[Regulation 3,Part B.II.D.1.a]. Condensate Truck Loading is subject to permitting because the site is and exploration and production facility that submerge fills more than 16,308 barrels of condensate per year ,[Regulation 3,Part B.II.D.1.1]. Regulation 3, Part B, Section III: Sources completing a permit to construct in designated nonattainment areas with projected controlled annual emissions of any pollutant for which an ambient air quality standard has been designated where such emissions will be greater than 25 tpy are subject to public comment and hearing requirements. The facility is subject to these regulations because VOC emissions are greater than 25 tpy[Regulation 3,Part B.III.C.1.a]. Regulation 3 requires that new minor sources in designated nonattainment areas shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance. The facility is a synthetic minor source within a nonattainment area and is required to apply RACT to facility sources of NO.and VOCs. The facility has met these requirements by following applicable requirement of Regulation 7 for sources of NO,and VOCs on site. Regulation 3, Part C: This facility will continue to operate as a synthetic minor source with respect to the Title V Operating Permit Program. The facility will not be required to submit a Title V Permit application within 12 months of startup. Regulation 3, Part D: This facility is not a listed source in Regulation 3, Part D, Section II.A.25 and therefore would trigger Prevention of Significant Deterioration (PSD) requirements if emissions exceed 250 tpy of any criteria pollutant. The facility is located in the nonattainment 8-hour Ozone Control Area where a major source for non-attainment new source review(NA- NSR)has the potential to emit more than 50 tpy for VOCs or NOR. This facility as proposed will be a synthetic minor stationary source with respect to PSD and NA-NSR; therefore, it is not subject to this regulation. Regulation 7, Part D Section I Oil and Gas Ozone Control Area Regulations 1 Regulation 7, Part D Section I.C: Section II.C applies to all condensate collection, storage and handling facilities located in the 8-hour Ozone Control Area. All new or modified storage tanks after February 1, 2009 must control VOC by at least 95% during the first 90 days of production. Any combustion device installed after January 1, 2017 must be equipped with an auto-igniter. The tanks are subject to this section and were controlled during the first 90 days of production.The combustion devices on site were installed prior to January 1,2017 and are equipped with auto-ignitors. Regulation 7,Part D Section I.D.1,I.D.2,I.F.1 and I.F.1:These sections apply to all condensate collection, storage and handling facilities located in the 8-hour Ozone Control Area with uncontrolled actual VOC emissions greater than 2 tpy. Operators with more than 30 tpy of system wide uncontrolled emissions must reduce VOC emissions system-wide by at least 70% on a calendar week basis from October through April and at least 90% from May through September until April 30, 2020. Weekly system-wide controls must be reported to the Division. The condensate tanks at this facility are subject to these sections and are included on Bonanza Creeks system wide control report. Regulation 7, Part D Section I.D.3 and I.F.2 and I.F.3: These sections apply to all condensate collection,storage and handling facilities with uncontrolled actual VOC emissions greater than 2 tpy in the 8-hour Ozone Control Area. Storage Tanks constructed on or after March 1, 2020 must control VOC emissions by at least 95% upon commencement of operations. Storage Tanks constructed prior to March 1, 2020 must control VOC emissions by at least 95% by May 1, 2020. Storage tanks must install controls within 60 days of exceeding 2 tpy uncontrolled actual VOC emissions. The produced water and oil storage vessels are all manifolded together via a liquid line and therefore are considered one "storage tank" for applicability purposes. The total emissions from the storage tank exceed 2 tpy uncontrolled actual VOC emissions and are subject to these sections. Regulation 7, Part D Section I.E: Section I.E applies to all existing storage tanks at oil and gas production facilities required to be controlled under Regulation 7, Part D Section I. Audio, visual,olfactory (AVO) inspections are required not more than every seven(7) days but at least every thirty one (31) days until April 30, 2020. Starting May 1, 2020 weekly AVO inspections are required. The storage tanks at this facility are required to install control equipment per Section I.D and are thus subject inspection, recordkeeping and reporting requirements of this section. Regulation 7, Part D Section I.J.2: This section applies to reciprocation compressors located between well production facilities and transmission facilities in the 8-hour Ozone Control Area. These compressors are required to replace rod packing every 26,000 operating hours or thirty six (36) months. Records of operating hours and replacement dates is also required. The reciprocating compressors at this facility are located at a well production facility are not subject to this requirement. Regulation 7, Part D Section I.L: Section I.L applies to well production facilities with uncontrolled actual VOC emissions greater than 1 tpy (highest emitting tank or facility wide emissions) and all natural gas compressor stations located in the 8-hour Ozone Control area. Compressor stations must conduct leak inspections quarterly starting within 90 days of startup. Well production facilities must conduct leak inspections annually or semi-annually (depending on emissions)starting within 30 days of commencing operations.This facility is considered a well production facility with storage tanks. Based on the uncontrolled VOC emissions, this facility is required to perform leak inspections on a monthly basis. Regulation 7,Part D Section II Oil and Gas State-Wide Regulations 2 Regulation 7,Part D Section II.C.1.:This section applies to all condensate collection,storage and handling facilities with uncontrolled actual VOC emissions greater than-2 tpy statewide.Storage Tanks constructed on or after March 1, 2020 must control VOC emissions by at least 95% upon commencement of operations. Storage Tanks constructed prior to March 1, 2020 must control VOC emissions by at least 95% by May 1,2021.The produced water and oil storage vessels are all manifolded together via a liquid line and therefore are considered one "storage tank" for applicability purposes. The total emissions from the storage tank exceed 2 tpy uncontrolled actual VOC emissions and are subject to this section. Regulation 7, Part D Section II.C.2 and II.C.3.: Section II.C.2 and II.C.3 applies to all storage tanks at oil and gas production facilities required to be controlled under Regulation 7, Part D Section I.D or II.C.1. A STEM plan must be developed and followed. Inspections of the storage tank must occur Monthly, quarterly or semi-annually (depending on emissions). The storage tanks are subject to control requirements under both I.D and II.C.1 and is therefore subject to this section. Based on the uncontrolled VOC emissions, this facility is required to perform STEM inspections on a monthly basis. Regulation 7, Part D Section II.C.4.: Section II.C.4 applies to all storage tanks at oil and gas production facilities,compressor stations and gas processing plants constructed or modified on or after May 1,2020.Storage tanks constructed or modified on or after May 1, 2020 must install equipment to determine quantity of liquid stored. Storage tanks constructed or modified on or after January 1, 2021 must install equipment to determine quantity and quality of liquid stored. Signage must be posted and annual training is required. This regulation does not apply to the storage tanks onsite because they were constructed prior to May 1,2020 and have not been modified. Regulation 7, Part D Section II.C.5.: Section II.C.4 applies to oil and gas production facilities, compressor stations and gas processing plants that loadout 5,000 barrels per year or more of hydrocarbon liquids. Facilities are required to use submerged fill and vapor return or control equipment. Facilities constructed on or after May 1, 2020 must be in compliance upon startup. Facilities constructed before May 1, 2020 must be in compliance by May 1, 2021. The facility is subject to this section because it loads out more than 5,000 barrels of hydrocarbon liquid per year. Regulation 7, Part D Section II.E.4: Section II.E.4 applies to well production facilities with uncontrolled actual VOC emissions greater than 1 tpy (highest emitting tank or facility wide emissions)and all natural gas compressor stations. This facility is considered a well production facility with storage tanks that is not within 1,000 feet of an occupied area. Based on the uncontrolled VOC emissions from the highest emitting tank, this facility is required to perform AIMM inspections monthly and AVO inspections monthly. Regulation 7, Part D Section II.F: Section II.F applies to gas coming off a separator produced during "normal" operations from newly construction, hydraulically fractured, or recompleted wells after August 1, 2014. This facility is subject to the gathering and control requirements of Part D II.F because the wells onsite were constructed after August 1,2014. Regulation 7, Part D Section II.G: Section II.G applies to downhole well maintenance, well liquids unloading events, and well plugging events. This facility is subject to the best management practices, record keeping and report requirements of this rule for any downhole well maintenance,well liquids unloading events,and well plugging events that occur on site. Regulation 7, Part D Section III: Section III applies to pneumatic controllers that are placed in service on or after February 1, 2009 in nonattainment areas, and pneumatic controllers statewide that are placed in service on or after May 1,2014. The facility is located inside the non- 3 attainment area and has complied with this regulation by installing only pneumatic controllers that emit VOCs in an amount less than or equal to a low-bleed pneumatic controller.This facility will follow the inspection,enhanced response,record keeping and reporting requirements. Regulation 7, Part D Section V: Section V requires oil and natural gas operations and equipment at or upstream of a natural gas processing plant submit an annual actual emissions report. The facility is located upstream of a natural gas processing plant and will follow the reporting requirements of this section. 40 CFR 60,New Source Performance Standards 40 CFR 60 Subpart Kb - Standards of Performance for Volatile Organic Liquid Storage Vessels (Induding Petroleum Liquid Storage Vessels): Subpart Kb applies to storage vessels which commence construction, modification or reconstruction after July 23, 1984. The storage tanks located at the facility are exempt from the requirements of this subpart under §60.110b(d)(4), as they are used for condensate storage prior to custody transfer and have a capacity less than 1,589,874 m3. 40 CFR 60 Subpart OOOO - Standards of Performance for Crude Oil and Natural gas Production, Transmission and Distribution for which Construction, Modification or Reconstruction Commenced after August 23, 2011, and on or before September 18, 2015: Subpart OOOO applies to affected facilities that commenced construction, reconstruction, or modification after August 23, 2011 and on or before September 18, 2015. Affected facilities include: gas well affected facilities; centrifugal compressors with wet seal degassing systems; reciprocating compressors; continuous-bleed natural gas actuated pneumatic controllers; storage vessels containing crude oil, condensate, produced water or a mixture thereof; equipment leaks of VOC at natural gas processing plants; and sweetening units at natural gas processing plants constructed,modified or reconstructed after August 23,2011 and on or before September 18, 2015. This facility is a well site and is neither a compressor station nor a natural gas processing plant. Storage Vessel Affected Facility: Each storage vessel constructed after August 23,2011 and before September 18, 2015, that emits VOC emissions at or greater than 6 tons per year (as determined by the maximum average daily throughput) is subject to the emissions control (95% DRE), recordkeeping and reporting requirements of this subpart. Legally and practically enforceable limits may be accounted for in determining VOC emission from storage vessels for applicability to this subpart. The storage tanks onsite were constructed in January 2014, however each storage vessel emits less than 6 tons per year after accounting for legally and practically enforceable limits, and as such the storage vessels are not an affected facility under this subpart. Pneumatic Controller Affected Facility:All continuous bleed pneumatic controllers must be low or no bleed (≤6 scf/hr natural gas bleed rate). High bleed pneumatic controllers, if they must be used,are subject to the tagging and reporting requirements of this subpart. All pneumatic controllers at the site are either intermittent, low (≤6 scf/hr natural gas bleed rate) or no bleed and as such not applicable to the tagging and reporting requirements of this subpart. Reciprocating Compressor Affected Facility: All reciprocating compressor affected facilities are those that have a single reciprocating compressor located between the wellhead and the point of custody transfer is applicable to this subpart. A reciprocating compressor located at a well site,or an adjacent well site and servicing more than one well site,is not an affected facility under this subpart. Because the location is a well site, the reciprocating compressor(s) at the site are not subject to the maintenance practices, 4 recordkeeping and reporting requirements of this subpart. Well Affected Facility: The 5 onsite wells were completed prior to September 18, 2015 and were drilled principally for oil, as permitted with the COGCC. Therefore, these existing wells are not subject to the reduced emissions completions requirements in OOOO. 40 CFR 60 Subpart 0000a - Standards of Performance for Crude Oil and Natural Gas Facilities for which Construction, Modification or Reconstruction Commenced After September 18, 2015: Subpart 0000a regulates certain: well affected facilities (oil and gas wells); centrifugal compressors with wet seal degassing systems; reciprocating compressors; continuous-bleed natural gas actuated pneumatic controllers; storage vessels containing crude oil, condensate, produced water or a mixture thereof; equipment leaks of VOC at natural gas processing plants; sweetening units at natural gas processing plants; pneumatic pump affected facilities; and the collection of fugitive emissions components at a well site or at a compressor station constructed,modified or reconstructed after September 18,2015.The site is considered a well site under this regulation. Storage Vessel Affected Facility:Each storage vessel that emits VOC emissions at or greater than 6 tons per year (as determined by the maximum average daily throughput) is subject to the emissions control (95% DRE), recordkeeping and reporting requirements of this subpart. Legally and practically enforceable limits may be accounted for in determining VOC emissions from storage vessels for applicability to this subpart. These storage vessels were constructed prior to September 18, 2015 and are therefore not an affected facility under OOOOa. Pneumatic Controller Affected Facility:All continuous bleed pneumatic controllers must be low or no bleed (≤6 scf/hr natural gas bleed rate). High bleed pneumatic controllers, if they must be used, are subject to the tagging and reporting requirements of this subpart. All pneumatic controllers at the site are either intermittent, low (≤6 scf/hr natural gas bleed rate) or no bleed and as such not applicable to the tagging and reporting requirements of this subpart. Reciprocating Compressor Affected Facility: All reciprocating compressor affected facilities are those that have a single reciprocating compressor located between the wellhead and the point of custody transfer is applicable to this subpart. A reciprocating compressor located at a well site,or an adjacent well site and servicing more than one well site,is not an affected facility under this subpart. Because the location is a well site, the reciprocating compressor at the site is not subject to the maintenance practices, recordkeeping and reporting requirements of this subpart. Collection of Fugitive Emissions Components: The collection of fugitive emission components located a well site are subject to a Leak Detection and Repair (LDAR) program. The facility was constructed prior to September 18, 2015 and has not been modified. The fugitive emission components are not subject to this subpart. 5 Hello