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Home My WebLink About20210059.tiffCOLORADO Department of Public Health & Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 December 30, 2020 Dear Sir or Madam: RECEIVED JAN 0 4 2021 WELD COUNTY COMMISSIONERS On December 31, 2020, the Air Pollution Control Division will begin a 30 -day public notice period for Bonanza Creek Energy Operating LLC - Mustang 14-26 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 a:t Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Public Notice Coordinator 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe Jared Potis, Governor I Jilt Hunsaker Ryan, MPH, Executive Director Tub1�c Rem;et,J O1 /13/21 Cc . Pt_(TP) ttL(Ds/sR) pta(SH/ER/cH/cw) o6(smi) ` 01/07/ al 2021-0059 Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating LLC - Mustang 14-26 Production Facility - Weld County Notice Period Begins: December 31, 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 LLC Facility: Mustang 14-26 Production Facility Oil and Gas well production facility NWSW Section 26 T4N R63W Weld County The proposed project or activity is as follows: Applicant proposes to modify synthetic minor facility to remain under the new non -attainment area major source limit of 50 tpy to remain a synthetic minor facility The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non -attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 18WE0843 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: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 COLORADO Department of Public Health Et Environment COLORADO Air Pollution Control Division Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the Permit number: Date issued: Issued to: CONSTRUCTION PERMIT 18WE0843 Issuance: 3 Facility Name: Plant AIRS ID: Physical Location: County: General Description: Bonanza Creek Energy Operating Company, LLC Mustang 14-26 Production Facility 123/9FE4 NWSW Section 26 T4N R63W Weld County Well Production Facility Equipment or activity subject to this permit: Facility Equipment ID AIRS Point Equipment Description Emissions Control Description CNDTK-01 001 Three (3) 500 barrel fixed roof storage vessels used to store condensate. Enclosed Combustor PWT-01 002 One (1) 500 barrel fixed roof storage vessel used to store produced water. Enclosed Combustor ECD-01 003 Produced natural gas routed to enclosed combustor Enclosed Combustor L-1 004 Hydrocarbon Liquid Loading Enclosed Combustor 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 the specific general terms and conditions included in this document and the following specific terms and conditions. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days of the latter of commencement of operation or issuance of this permit, l submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/cdphe/air/manage-permit. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) COLORADO Air Pollution Control Division Department of Public Health & Environment Page 1 of 17 Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self - certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at www.colorado.gov/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section III.G.2.) 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline. (Regulation Number 3, Part B, Section III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Regulation Number 3, Part B, Section III.E.) 5. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility Equipment ID AIRS Point Tons per Year Emission Type PM2.5 NOX VOC CO CNDTK-01 001 --- --- 4.3 --- Point PWT-01 002 --- --- 0.2 --- Point ECD-01 003 --- 7.4 35.0 33.8 Point L-1 004 --- --- 0.2 --- 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. COLORADO Air Pollution Control Division Depanment of Public Health Et Environment Page 2 of 17 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. 7. The owner or operator must use the emission factors found in "Notes to Permit Holder" to calculate emissions and show compliance with the limits. The owner or operator must submit an Air Pollutant Emission Notice (APEN) and receive a modified permit prior to the use of any other method of calculating emissions. 8. 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 Number 3, Part B, Section III.E.) Facility Equipment ID AIRS Point Control Device Pollutants Controlled CNDTK-01 001 Enclosed Combustor (Make: Crimson Model: CE1000, Serial Number: BCEI-LP0418) VOC and HAP PWT-01 002 Enclosed Combustor (Make: Crimson Model: CE1000, Serial Number: BCEI-LP0418) VOC and HAP ECD-01 003 Enclosed Combustor (Make: Crimson Model: CE1000, Serial Number: BCEI-LP0418) VOC and HAP L-1 004 Enclosed Combustor (Make: Crimson Model: CE1000, Serial Number: BCEI-LP0418) VOC and HAP PROCESS LIMITATIONS AND RECORDS 9. 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 Equipment ID AIRS Point Process Parameter Annual Limit CNDTK-01 001 Condensate throughput 62,415 barrels PWT-01 002 produced Water throughput 68,055 barrels ECD-01 003 Natural gas venting 155.06 MMscf L-1 004 Condensate loaded 62,415 barrels The owner or operator shall monitor monthly process rates based on the calendar month. COLORADO Air Pollution Control Division Department of Publtc Health b Environment Page 3 of 17 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. 10. Point 003: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from this point using the flow meter. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. 11. The owner or operator must operate a flame detection system that monitors the combustor pilot system for the presence of a pilot light flame. If a flame is not detected, the facility will shut-in all of the wells serviced by this facility, such that the wells cannot produce to the facility. 12. At a minimum of a weekly basis, the owner or operator must monitor the control device for the presence of a pilot light and an operational auto -igniter. These monitoring records shall be used to calculate control device downtime. During periods without the presence of a pilot light and/or an operational auto -igniter, the flow volume from emissions source(s) shall be assigned a 0% control efficiency. These monitoring records must be maintained for a period of five (5) years, and a summary of monthly pilot light downtime and vapor flow during pilot light downtime shall be provided to the division upon request. STATE AND FEDERAL REGULATORY REQUIREMENTS 13. The permit number and ten digit AIRS ID number assigned by the Division (e.g. 123/9FB9/xxx) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 14. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 15. Point 001 and 002: 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 this storage tank 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) 16. Points 001, 002, 003, and 004: The combustion device covered by this permit is subject to Regulation Number 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.23; and be designed so that an observer can, by means of visual COLORADO Air Pollution Control Division Department of Public Health Fs Environment Page 4 of 17 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. 17. Point 001 and 002: The storage tank 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 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. 18. Point 001 and 002: 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. 19. Point 004: 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 Sections II.C.5.a.(i)(A) or II.C.5.a.(i)(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. 20. Point 004: Storage tanks must operate without venting at all times during loadout. (Regulation Number 7, Part D, Section II.C.5.a.(ii)) 21. Point 004: 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 recovery and disposal equipment at a back -pressure less than the pressure relief valve setting of transport vehicles. COLORADO Air Pollution Control Division Department of Pubttc Health b Environment Page 5 of 17 • 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. 22. Point 004: The owner or operator must perform the following observations and training (Regulation Number 7, 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. 23. Point 004: 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 Sections II.C.5.a.(iii) and II.C.5.a.(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. 24. Point 004: Air pollution control equipment used to comply with this Section II.C.5. must comply with Section II.B., be inspected in accordance with Sections 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)) 25. Point 003: The separator covered by this permit is subject to Regulation 7, Part D, Section II.F. 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 commencement of operation by air pollution control equipment that achieves an COLORADO Air Pollution Control Division Department of Public Health b Environment Page 6 of 17 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. 26. 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 £t MAINTENANCE REQUIREMENTS 27. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (0&tM) 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 OEtM plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. This source is not required to conduct initial testing, unless otherwise directed by the Division or other state or federal requirement. Periodic Testing Requirements 29. Points 001, 002, 003 and 004: On an annual basis, the owner or operator must conduct a source compliance test to measure the mass emission rates of the pollutants listed below, demonstrate compliance with the emissions limit in this permit, and to demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC). During the test, the owner or operator must measure: • volumetric flow rate (scf/hr) to the inlet of the combustion device (V;); • mass emission rates of VOC (lb/hr) at the inlet of the control device (Mvoc;) using EPA or other division approved methods; • mass emission rates of VOC (lb/hr) at the outlet of the control device (Mvoco) using EPA or other division approved methods; • mass emission rates of NOx and CO (lb/hr) at the outlet of the control device (MNox and Mco respectively) using EPA or other division approved methods. • gas heat content; and • gas composition. Additionally, the following parameters may be required to be measured during the test: • combustion chamber temperature; • supplemental fuel flow rate; The destruction efficiency (DE) for VOC must be calculated using the following equation: COLORADO Air Pollution Control Division Department of Public Health Et Environment Page 7 of 17 DE (%) = 100 * (Mvoci — Mvoco) Mvoci The annual emission rate (tpy) of NOx and CO (ENox and Eco) shall be calculated using the following equations: (106 MNox)scf* P ENox 1* MMscfl (MC°l ( 6 scf l Eco — \ Vi I * \10 MMscfl * P Where P = The permitted annual process limit(s) (MMscf/yr or bbl/yr) for each point subject to this performance test For any points based on a liquid throughput process limit (bbl/yr), the annual emission rate (tpy) of NOx and CO (ENox and Eco) shall be calculated using the following equations: ENox = (MNO x) * (GOR) * P Vi Eco = (Mco)* (GOR) * P Vi Where GOR = the gas -to -oil ratio (scf/bbl) as calculated in the permitting of that point, as established in the Notes to Permit Holder section of this permit. The sum of the annual emission rates of NOx and CO for all points subject to performance testing, as calculated above, must be less than or equal to the following annual emissions limits as previously stated in this permit: Pollutant Annual Limit (tpy) NOx 7.9 CO 36.1 The test protocol, test, and test report must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual. The test protocol must include testing under all operating scenarios of the control device. The test protocol must be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test will be conducted without prior approval from the Division. Within thirty (30) days following completion of the test(s), a compliance test report must be submitted to the Division for review. Additional time may be granted upon written request. Any compliance test conducted to demonstrate compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the Process Limit(s) for that averaging time as indicated in the Process Limitations and Records section of this permit. (Regulation Number 3, Part B., Section III.G.3) COLORADO Air Pollution Control Division Department of Pubtic Health b Environment Page 8 of 17 Records of the annual compliance tests must be maintained by the owner or operator and made available to the Division for inspection upon request. Actual emissions calculations must be completed in accordance with PS Memo 20-02. If the results of any periodic compliance test do not demonstrate compliance with the emissions limits contained within this permit or do not demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC) for each operating scenario, the owner or operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address these inaccuracies. 30. Point 001: On an annual basis, the owner or operator must complete a site specific analysis ("Analysis'), including a compositional analysis of the pre -flash pressurized hydrocarbon liquid routed to the equipment covered in this permit. Testing must be in accordance with the guidance contained in PS Memo 05-01. Results of the Analysis must be used to demonstrate that the emissions factor established through the Analysis is greater than or equal to the emissions factor submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factors submitted with the permit application and established in the "Notes to Permit Holder" the operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address these inaccuracies. 31. Point 003: On an annual basis, the owner/operator must complete a site specific extended gas analysis ("Analysis") of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of the Analysis must be used to calculate site -specific emission factors for the pollutants referenced in this permit (in units of lb/MMSCF gas vented) using Division approved methods. Results of the Analysis must be used to demonstrate that the emissions factor established through the Analysis are less than or equal to, the emission factor submitted with the permit application and established herein in the "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this Analysis is greater than the emissions factor submitted with the permit application and established in the "Notes to Permit Holder" the operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address this/these inaccuracy(ies). ALTERNATIVE OPERATING SCENARIOS 32. Points 001, 002, 003 and 004: The control device may be replaced with a like -kind control device in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like -kind control device shall be the same make and model as authorized in this permit. All control device replacements installed and operated as authorized by this permit must comply with all terms and conditions of this construction permit. The owner or operator shall maintain a log on -site or at a local field office to record the start and stop dates of any control device replacement, the manufacturer, model number and serial number of the replacement control device. 33. Points 001, 002, 003 and 004: An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model, and serial number of the replacement control device must be filed with the Division within 14 calendar days of commencing operation of a replacement control device under the Alternative Operating Scenario provision. The APEN must be accompanied by the appropriate APEN filing fee and a actib-..4400 COLORADO Air Pollution Control Division Department of Public Health 8 Environment Page 9 of 17 cover letter explaining that the owner or operator is exercising an Alternative Operating Scenario and has replaced the control device. 34. Points 001, 002, 003 and 004: Within one hundred and eighty days (180) of startup of the replacement control device in accordance with the Alternate Operating Scenario provision, the owner or operator must conduct an initial source compliance test to measure the mass emission rates of the pollutants listed below, demonstrate compliance with the emissions limit in this permit, and to demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC). During the test, the owner or operator must measure: • volumetric flow rate (scf/hr) to the inlet of the combustion device (V,); • mass emission rates of VOC (lb/hr) at the inlet of the control device (Mvoo) using EPA or other division approved methods; • mass emission rates of VOC (lb/hr) at the outlet of the control device (Mvoco) using EPA or other division approved methods; • mass emission rates of NOx and CO (lb/hr) at the outlet of the control device (MNox and Mco respectively) using EPA or other division approved methods. • gas heat content; and • gas composition. Additionally, the following parameters may be required to be measured during the test: • combustion chamber temperature; • supplemental fuel flow rate; The destruction efficiency (DE) for VOC must be calculated using the following equation: DE (%) = 100 * (Mvoci — Mvoco) Mvoci The annual emission rate (tpy) of NOx and CO (ENoX and Eco) shall be calculated using the following equations: (MNox scflENox = I*(106 MMscfl * P (Mcol ( 6 scf l Eco = * \10 MMscf) Where P = The permitted annual process limit(s) (MMscf/yr or bbl/yr) for each point subject to this performance test For any points based on a liquid throughput process limit (bbl/yr), the annual emission rate (tpy) of NOx and CO (ENoX and Eco) shall be calculated using the following equations: MNox ENox = () * (GOR) * P Vi COLORADO Air Pollution Control Division Department of Public Health b Environment Page 10 of 17 Eco = (—Mco)* (GOR)* P Where GOR = the gas -to -oil ratio (scf/bbl) as calculated in the permitting of that point, as established in the Notes to Permit Holder section of this permit. The sum of the annual emission rates of NOx and CO for all points subject to performance testing, as calculated above, must be less than or equal to the following annual emissions limits as previously stated in this permit: Pollutant Annual Limit (tpy) NOx 7.9 CO 36.1 The test protocol, test, and test report must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual. The test protocol must include testing under all operating scenarios of the control device.The test protocol must be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test will be conducted without prior approval from the Division. Within thirty (30) days following completion of the test(s), a compliance test report must be submitted to the Division for review. Additional time may be granted upon written request. Any compliance test conducted to demonstrate compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the Process Limit(s) for that averaging time as indicated in the Process Limitations and Records section of this permit. (Regulation Number 3, Part B., Section III.G.3) Records of the initial compliance tests must be maintained by the owner or operator for a minimum of five (5) years and made available to the Division for inspection upon request. Actual emissions calculations must be completed in accordance with PS Memo 20-02. If the results of the initial compliance test do not demonstrate compliance with the emissions limits contained within this permit or do not demonstrate a minimum destruction efficiency of 98% for volatile organic compounds (VOC) for each operating scenario, the owner or operator must submit to the Division within 60 days, or in a timeframe as agreed to by the Division, a request for permit modification to address these inaccuracies. ADDITIONAL REQUIREMENTS 35. 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 COLORADO Air Pollution Control Division Department of Public Health Et Environment Page 11 of 17 For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. • 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. GENERAL TERMS AND CONDITIONS 36. 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. 37. 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. 38. 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. 39. 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. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 12 of 17 40. 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. 41. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 42. 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: Christopher Kester Permit Engineer Permit Histo Issuance Date Description Issuance 3 This Issuance Issued to Bonanza Creek Energy Operating Company, LLC Updated all points - updated process limits, and associated emission limits. Removed Point 005 Issuance 2 November 25, 2019 Issued to Bonanza Creek Energy Operating Company, LLC Point 001: Increased permit limits, updated SSEF Point 003: Increased permit limits, updated SSEF Point 004, 005: Added to permit Added annual compliance testing requirements Et AOS section for combustion device Issuance 1 February 5, 2019 Issued to Bonanza Creek Energy Operating Company, LLC. COLORADO Air Pollution Control Division Department of Public Health Er Environment Page 13 of 17 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. 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) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled Emissions (lb/yr) Controlled Emissions (lb/yr) 001 Benzene 71432 2,728 56 Toluene 108883 2,590 52 Ethybenzene 100414 368 8 Xylenes 1330207 793 16 n -Hexane 110543 17,670 354 002 Benzene 71432 476 10 n -Hexane 110543 1,497 30 003 Benzene 71432 10,090 202 Toluene 108883 10,972 220 Ethybenzene 100414 2,308 48 Xylenes 1330207 6,448 130 n -Hexane 110543 73,576 1,472 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. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 14 of 17 5) The emission levels contained in this permit are based on the following emission factors: Point 001: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source NOx 0.0680 (lb/MMBtu) 0.0680 (lb/MMBtu) AP -42 Ch. 13.5 CO 0.3100 (lb/MMBtu) 0.3100 (lb/MMBtu) VOC 6.8528 0.1371 proMax model based on a site - specific pressurized liquid sample 71432 Benzene 0.0437 0.00087 108883 Toluene 0.0415 0.00083 100414 Ethylbenzene 0.0059 0.00012 1330207 Xylene 0.0127 0.00025 110543 n -Hexane 0.2831 0.00566 Note: The controlled emissions factors for this point are based on the flare control efficiency of 98%. The GOR to be used in emissions calculations is 62.3 scf/bbl. Point 002: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.262 0.0052 Default for Weld County 71432 Benzene 0.007 0.00014 110543 n -Hexane 0.022 0.00044 Note: The controlled emissions factors for this point are based on the flare control efficiency of 98%. The GOR to be used in emissions calculations is 36 scf/bbl. Point 003: CAS # Pollutant Uncontrolled Emission Factors (lb/MMscf) Controlled Emission Factors (lb/MMscf) Source NOx 0.0680 (lb/MMBtu) 0.0680 (lb/MMBtu) AP -42 Ch. 13.5 CO 0.3100 (lb/MMBtu) 0.3100 (lb/MMBtu) VOC 22, 553.1 451.15 Mass Balance on a site -specific gas sample 71432 Benzene 65.1 1.30 108883 Toluene 70.7 1.42 100414 Ethylbenzene 14.9 0.30 1330207 Xylene 41.6 0.83 110543 n -Hexane 474.5 9.49 Note: The controlled emissions factors for this point are based on the flare control efficiency of 98%. COLORADO Air Pollution Control Division Department of Public Health b Environment Page 15 of 17 Point 004: CAS # Pollutant Uncontrolled Emission Factors lb/bbl Controlled Emission Factors lb/bbl Source VOC 0.236 0.00472 State default emission factors n -Hexane 0.0036 0.00072 Controlled emission factors are based on a combustor efficiency of 98%. The GOR to be used in emissions calculations is 1.79 scf/bbl. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five- year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This 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. 8) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A - Subpart KKKK NSPS Part 60, Appendixes Appendix A - Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A - Subpart Z MACT 63.600-63.1199 Subpart 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 COLORADO Air Pollution Control Division Department of Public Health b Environment Page 16 of 17 MACT 63.8980 -End Subpart NNNNN - Subpart XXXXXX COLORADO Air Pollution Control Division Department of Public Health Fr Environment Page 17 of 17 Colorado Air Permitting Project PRELIMINARY ANALYSIS - PROJECT SUMMARY Project Details Review Engineer: Package #: Received Date: Review Start Date: For Division Use Only vtiristopher Kester 42$294 Vg012020 11)16/2020 Section 01- Facility Information Company Name: County AIRS ID: Plant AIRS ID: Facility Name: Physical ,Address/Location: County: Type of Facility: .Exploration & Production. Well Pad What industry segment? Oil & Natural Gas Production_ & Processing Is this facility located in a. NAAQS non -attainment area? Yes If yes, for what pollutant? Ozone (NOx & VOC) Bonanza Creek Energy Operating. Company LLC 123 9FE4 ii quadrant of Section,;Township K.M,Range Snit Weld County Section 02 - Emissions Units In Permit Application Leave Blank - For Division Use Only AIRS Point # (Leave blank unless APCD has already assigned) Emissions Source Type Equipment Name Emissions Control? Permit # (Leave blank unless APCD has already assigned) Issuance # Self Cert Required? Action Engineering Remarks 001 Storage Tana - CND -I K -G1 Yes 18WE0843 3 Yes Permit Modification ^,ndensate 002 - - - - - Storage Tank _ PWT-02 Yes NE0843 3 Yes Permit - Modification rh' 003 ... - . Separator Venting. ECC- 01 Yes S"tE0843 O _ - Yes Permit Modification 004 - - Liquid Loading - L-1 Yes BttJE0843 s _ Yes Permit Modification Quadrant Section Township Range UN Section 03 - Description of Project Applicant is modifying- permit to stay below rew non -attainment area maids source threshold. This h•e a new synthetic, minor permit under the i- . i.-nit of 5OtpY - Sections 04, 05 & 06 - For Division Use Only Section 04 - Public Comment Requirements Is Public Comment Required? Yes If yes, why? Requesting Synthetic Minor Permit Section 05 - Ambient Air Impact Analysis Requirement Was a quantitative modeling analysis required? No If yes, for what pollutants? If yes, attach a copy of Technical Services Unit modeling results summary. Section 06 - Facility -Wide Stationary Source Classification Is this stationary source a true minor? Yes Is this stationary source a synthetic minor? Yes If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TV HAPs Prevention of Significant Deterioration (PSD) ❑ ❑ ❑ ❑ ❑ ❑ Title V Operating Permits (OP) 00020 0021 Non -Attainment New Source Review (NANSR) ❑ IA Is this stationary source a major source? hto If yes, indicate programs and which pollutants: SO2 NOx CO VOC PM2.5 PM10 TSP HAPs Prevention of Significant Deterioration (PSD) 000000 Title V Operating Permits (OP) 00000 000 Non -Attainment New Source Review (NANSR) 0 0 Tank(s) Emissions Inventory Section 01 -Administrative Information 'Facility AIRS ID: 123 County 9994 Plant Poin Section 02- Equipment Description Details Storage Tank Liquid Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: 'Three (3; 300 83,36fr+ce f storage vessels usaii tOr ondensate. Limited Process Parameter Section 03- Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Throughput= Requested Permit Limit Throughput= 62,415.0 Barrels (bbl( per year 62,415!0 Barrels (bbl) per year Requested Monthly Throughput= 5301.0 Barrels(bbl) per month Potential to Emit (PTE) Condensate Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas = Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = 6 Barrels (bbl) per year 2752.0 Btu/scf 62.3 scf/bbl Potential to Emit (PTE) heat content of waste gas routed to combustion device = Control Device 10.701.0 MMBTU per year 10.701 v MMBTU per year 10.701.0 MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Pollutant Condensate Tank Uncontrolled Controlled (Ib/hbp (Ib/blip (Condensate Throughput) (Condensate Throughput) Emission Factor source gg i Pollutant Pollutant Control Device Uncontrolled (Ib/MMBtu) (waste heat combusted) Uncontrolled (Ib/bbp 0,310O13263 (Condensate Throughput) Pilot Light Emissions Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/MMscf) (Pilot Gas Throughput) (Pilot Gas Heat Combusted) Emission Factor Source Emission Factor Source Section OS -Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 5Ox NOx VOC CO _.: 0.0 0.0 5.8 0.0 0.0 ._ 0.0 _._ 5.8 0.0• 0.0 0.0 0.0 _.. 0 =0 0.4 0.4 0.4 0.36 ?.. 3..._ 213.9 213.9 :.3 213.9 1.7 1.7 _.. ... .., ___.. Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year( Benzene Toluene Ethylbenzene 2727.5 2727.5 _.._ V27.5 54.5 1590.2 2590.2 51-8 2390.2 51.8 368.22 3:6532 74 363..2, .: 2 of 18 ICAPA\2018\18WED643.CP3 Storage Tank(s) Emissions Inventor; xyiene n -Hexane 224 TMP 792.7 732.7 15.9 353.4 792.7 17869.7 17669.7 17669.7 137.3 137 3 2.7 137.3 3 of 18 KAPA\2018\18WE0843.CP3 Storage Tank(s) Emissions Inventory Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B 5. _._e. requires a permit Regulation 7, Part D,Section I:C, D, E, F Hoinge tank is su biect to Regulation 7, Part D. Section I,C-F Regulation 7, Part D,Section I.G, C .,,,,),-tse Tank is not to Roguintion'7, Section 123 Regulation 7, Part D,Section II.B, C.1, C.3 _, 3 , �, . n , 0, 5 t ., 11 C._ 3 C.3 Regulation 7, Part D,Section II.C.2 t,, net -elation 7 Par D. Section ii.C.2 Regulation 7, Part D,Section II.C.4.a.(i) .. :,,,,t to _ , on 7. pa^ C., Section ,- 4. - Regulation 7, Part D,Section II.C.4.a.(ii) __..... -- Re ,:_,.o-, 7., a: D Section ,- Regulation 6, Part A, NSPS Subpart Kb Star, :. t� tSSP5 Kc- Regulation 6, Part A, NSPS Subpart 0000 ;Ant enough inform. lion NSPS Subpart 0000a =lot =enough info nna.ion Regulation 8, Part E, MACE Subpart HH Storage Tank is not. subiect to MAST OH ' (See regulatory applicability worksheet for detailed analysis) Section 07 - Initial and Periodic Sampling and Testint;_Requirements For condensate or crude oil tanks, does the company use the state default emissions factors to -` x estimate emissions? If yes, are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than or equal to 80 tpy? If yes, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03 Does the company use a site specific emissions factor to estimate emissions? Ryes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted (for produced water tanks, a pressurize liquid sample must be analyzed using flash liberation analysis)? This sample should be considered representative which generally means site -specific and collected within one year of the application received date. However,if the facility has not been modified (e.g., no new wellsbrought on-line), then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. 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 Emission factors have not been changed. Only adjusting pro AIRS Point it Process it 01 Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) SCC Coae Uncontrolled Emissions Pollutant Factor Control% Units PM10 0 lb/1,000 gallons Condensate throughput PM2,5 .,13 0 lb/1,000 gallons Condensate throughput SOx ` 17.! 0 lb/1,000 gallons Condensate throughput NOx C,_8 0 lb/1,000 gallons Condensate throughput VOC 133.16 98 16/1,000 gallons Condensate throughput CO 1.27 0 lb/1,000 gallons Condensate throughput Benzene 1_04 98 lb/1,000 gallons Condensate throughput Toluene 5.029 98 lb/1,000 gallons Condensate throughput Ethylbenzene „_7 98 Ib/1,000: gallons Condensate throughput Xylene 3.30 98 lb/1,000 gallons Condensate throughput n -Hexane 5.7- 93 Ib/1,000.gallons Condensate throughput 224 TMP 0 05 98 lb/1,000 gallons Condensate throughput 4 of 18 K:\PA\2018\18W E0843.CP3 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below ore determined based on requested emissions. Calomdolarion 3 Par. A and B-APEN and ts Permit Requiremen :eiJrn..Attolnn�er,t ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2TPY(Regulation 3, Part A, Section ll.O.l.a)7 ® Source Requires an APEN. Go to 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 22/31/2002 (See PS Memo 05-01 Definitions 1.12 and1.14 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greater than STPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY(Regulation% Part%Section 11.0.31? NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this ind'vidualsource greater than 1 TPY(Regulation 3, Part A, Section ll.D.1.a)? 2. Is the construction date (service date) prior to 12/30/2002 and not modified after 12/31/2002 (See PS Memo D5-01 Definitions 1.12 and114 and Section 2 for additional guidance on grandfather applicability)? 3. Are total facility uncontrolled VOC emissions greaterthen2TPY, NOx greater than STAY or CO emissions greater than 10 TP11(Regulation 3, Part B, Section ll.D.l)? I5a,r_ colorado Regulation 7 Part D. Section I.C-F & G 1. Is this storage tank located In the 8 -hr ozone control area or any ozone non -attainment area or attainmentimalntenance area (Regulation 7, Part 0, Section IA.1)7 2. Is this storagetank located at oIl and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gas processing plant (Regulation 7, Part %Section IA.1)? 3. Is this storage tank located at a natural gas processing plant (Regulation 7, Part D, Section I.G)? 4. Does this storagetank contain condensate? 5. Does thb storage tank exhibit "Flash"(ig. staring non -stabilized liquids) emissions (Regulation], part O, Section l.G.2)? 6. Are uncontrolled actual emisslonsofthis storagetank equalto or greater than 2 tons per year VOC (Regulation 7, Part D, Sefton 113.alli)l? IStorirign tz, suble tto Regulation ?.Poi Part D, section I.C3 —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Part D, Section %G2 —Emission Estimation Procedure Part D,Sectionl.D—Emissions Control Requirements Part 0, Section I.E—Monitoring Part 0, Section I.F —Recordkeeping and Reporting Part %Section LG.2- Emissions Control Requirements Part 0, Section I.C.I.a and b —General Requirements for Air Pollution Control Equipment —Prevention of Leakage Colorado Regulation] Part%Section ll 1. Is this storagetank located at a transmission/storagefacilhy? 2. is this storagetank' located at an oil and gas exploration and production operation, well production facility', natural gas compressor stations or natural gas processing plant`(Regulation 7, Part D, Section ll.C)7 3. Does thsstmagetank have a fixed roof (Regulation 7, Part D, Section ll.A.20)7 4. Are uncorRmlled actual embsionsaf this storage tank equal to or greater than 2 tons per year VOC (Regulation 7, Part D, Section ll.C.1.0? Yes Go to next question Source Requires a permit Source Requires an APED, Go to Go to next question Source Requires a permit Continue - You have Indicated th Continue - You have Indicated th Storage Tank n not subject to Re Continue- You have Indicated th Go to the next question - You ha Go to the next question Source is subject to parts of Reg, Part D, Section II.B—General Provisions for Air Pollution Control Equipment and Prevention of Emissions Part D, Section II.C.1- Emissions Control and Monitoring Provisions Part D, Section II.C.3 - Recordkeeping Requirements 5 0 sthe storage k taily t bill d Iq d (Regtion Part O, Section%Cab)7 I"gtgS"A��Sourcebsubject to all provision: I.: sure Part D, Section II.C.2-Capture and Monitoring for Storage Tanks fitted with Air Pollutlon Control Equipment I tit trolledg tank locateda[ Ilpod ctf Ity, Ig pressor Nation, or natural gas processplant constructed on or after May 1, 2020 or located at a facilty that was modified on or after May 1, 2020, such 6 that additional (led storeconstructed[ 'p[dincrease in throughput of hydrocarbon liquids or produced water (Regulation 7, Part D, Section ll C4a(ij? r, StoageTank is not subject to RE Is the controlled rtorage tank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed on or after January 1, 2021 or located at a facilitythat was modified on or after January 1, 7. 2021, such that.an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydroorbon liquids or produced water (Regulation 7. Part D, Section II.C.4.a.liii? Storage Tank is not subject NSPS 40 CFR. Part 60, subpart Kb, Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the individual storage vessel capacity greater than or equal to 75 cubic meters (m) [-472 BBLs] (40 CFR 60.110b(a))? 2. Does the storage vessel meet the following exemption in 60.111b(d)(4)? a. Dbes the vessel has a design capacity less than or equal to 1,589.874 m'[-10,000 BBL] used for petroleum' or condensate stored,processed, or treated prior to custody transfer' as defined In 60.111h? 3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after July 2%1984(40 CFR 60.1106(a))7 4. Does the tank meet the definition of"storage vessel"' in 60.I11b? 5. Does the storage vessel store a"volatile organicliquid(VOL)"'as defined In 60.1110 G. Doesthe.storage vessel meet any one of the fallowing additional exemptions: a. n thestorage vessel a pressure vessel designed to operate In excess of 204.9 kpa[-29.7 psi] and without emissions to the atmosphere(60.1106[d)(2))?; or b. Thedesign capacity Is greater than or equalto 151 m' [-950 BBL] and stores a liquid with a maximum true vapor pressure` less than 3.5 kPa (60.110b(b))?; or c. Thedesign capacity Is greater than or equal to 7511.4' [-472 BBL] but less than 151m' [-950 BBII and stores a liquid with a maximum true vapor pressures less than 15.0 kPa[60.110b(b))? 7. Does the storage tank meet either one of the following exemptions from control requirements: a. The design capacity is greaterthan or equalto 151 m' [`950 BBL] and stares a liquid with a maxmum true vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa?; or b. Thedesign capacity Is greater than or equal to 75 M' [-472 BBL] but less than 151 m' [-950 BBL] and stores a liquid with a maximum true vapor pressure greater than or equal to 15.0 kPa but less than 27.6 kPa? is:Yet'Alb Wntt, fi?S eh 4a CFR, Part 60,Subpert 0000/Oo00a, standards of Performance for Crude Oil and Natural Gas Production.Tansmission and Distribution 1. IS this storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this storag vessel constructed, reconstructed, or modRied(see definitions 40CFR, 60.2) between August 23, 2011 and September 18, 2015? 3. Was this storage vessel constructed, reconsructed, or modified (see definitions 40 CFR, 60.2] after September 18, 2035? 4. Are potential VIOL emissionsfrom the individual storage vessel greater than or equal to 6 tons per year? 5. Does this storage vessel meet the definition of"storage vessel° per 60.5430/60.543ov? 6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels In 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart HH? kDen ogh'n,..,.nr .,,n [Nate: If a storage vessel is previously determined To be subject to NSPS 0000/0000a due. emissions above 6 tons per year VOC onthe appihabllity determination date, it should remain subject. NSPS 0000/0000a per 60.5365(e)(2)/60.53653(e)(2) even If potential VOC emissions drop below 6 tons per year] 40 CFR. Part 63, Subpart ',ACT Hi%Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. Afxility that processes, upgrades or Wares hydrocarbon liquids' (63.760(a)(2)); OR b. Afacility that processes, upgrades or stares natural gas prior to the point at which natural gas enters the natural gas transmission and storage source category or is delivered to a final end user' (63.760(a)(3))? 2. 'stile tank located et a facility that's major' for HAPs? 3. Does the tank meet the definition of"storage vessel"a in 63.761? 4. Does the tank meet the definition of"storage vessel with the potential for flash emissions"' per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60, Sub art Kb or Sub art 0000? to n,e Ta.t4 is not•.ubiect' to:IAC' Subpart A, General provisions per 463.764 (a) Table 2 46%766- Emissions Control Standards 4.173 - Monitoring §63.774-Recordkeeping 4.175 - Reporting RACT Review RACr review is required If Regulation 7 does not apply AND If the tank Is In the non -attainment area. If the tank meets both criteria, then review PACT requirements. Disclaimer Continue - You have indicated th I'/es 'Continue- You have Indicated th Storage Tank is not subject MAC This document assists operators with determining applicability of certain requirements of the Clean Air Ash its implementing regulations, and Air Quality Control Commission regulations. This dccument is not a rule or regulation, and the analysis it conteins may not apply to a particular situation based upon the individual fads and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language. of this document and the language of the Clean Air Act„ its implementing regulations, and Air Qualify Control Commission regulations, the language of the statute or regulation will control. The use of non-mendsfcry language such as "recommend,""may,"'should,"and ien,"Is intended to describe APCQ interpretations and recommendations. Mandatory terminology such es "musr and "required"ere intended to describe contmlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of Itself. Section 01- Administrative Information 'Facility AIRS ID: County Plant Point Section 02- Equipment Description Details Storage Tank Liquid Detailed Emissions Unit Description: Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Enclosed,Olmbusigr • Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions -Storage Tank(s) Actual Throughput= 'Requested Permit Limit Throughput= 22,685.0 Barrels (hbl) per year 68.055.0 Barrels (bbl) per year dwater. Requested Monthly Throughput = Barrels (bbl) per month Potential to Emit (PTE) Condensate Throughput = Secondary Emissions - Combustion Device(s) Heat content of waste gas= Volume of waste gas emitted per BBL of liquids produced = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device= 88,055.0 Barrels (bbl) per year Potential to Emit (PTE) heat content of waste gas routed to combustion device = Control Device ' MMBTU per year MMBTU per year • ° MMBTU per year Section 04- Emissions Factors & Methodologies Will this storage tank emit flash emissions? Pollutant Control Device Pollutant Produced Water Tank Uncontrolled Controlled (lb/bbl) (lb/bbl) (Produced Water Throughput) (Produced Water Throughput) Uncontrolled (Ib/MMBtu) (waste heat combusted) Uncontrolled (lb/bbl) (Produced Water Throughput) 0.0075 MIIIMEMIll ®3E5S IMIIIE IIMMSMIId Emission Factor Source Emission Factor Source Pollutant Pilot Light Emissions Uncontrolled (Ib/MMBtu) Uncontrolled (Ib/MMscf) (Pilot Gas Throughput) (Pilot Gas Heat Combusted) Emission Factor Source Section 05 - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM10 PM2.5 SOx Nox VOC CO 0.0 J 00 u0 ..._ 2.3 3.0 0..; 2 3 0.3 0.0 00 00-_ 00 0.1 00 O1T. 07 212 33 3.0 01 3a .e. 30.3 0.6 0.2 0.2 0.37 .,._ 96.5 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ihs/year) (Ibs/year) Requested Permit Limitr Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene 476.4 153.8 3.2 476 4 9.5:3 0.0 0.0 0.0 _— 0.0 0.;, v.., .... _- 7 of 18 K:\P A\2018\38 W ED843. CP3 Storage Tankisj Emissions Inventory xyiene n -Hexane 224 TMP 0,0 0.0 0,0 0.0 1497.2 499.1 1497.2 0.0 0.0 0.0 0.0 8 of 12 ICAPA\2018\18WE0843.CP3 Storage Tank(s) Emissions Inventory Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Source requires a permit Regulation 7, Part D,Section I.C, D, E, F Storage tank, is subject to Peg:Poton 7. Part O. Section I.C-F Regulation 7, Part D,Section I.G, C Storage Tank is not subject to Regulation 7, Section ITS Regulation 7, Part .D,Section II.B, C:1, C.3 Storage a .. Regulation 7 Part D, Section IM, 8, G.J. 4. C.3 Regulation 7, Part D,Section II.C.2 Storage -taut : a j c Regulation 7. Part D, Soution II.C.2 Regulation 7, Part D,Section ll.C.4.a.(i) Storage Tu . . -Regulation 7, Part D, Section kk.C 4..(I) Regulation 7, Part D,Section II.C.4e.(ii) __ _ _ _ ._;teen iat .m 7. Part. Section II, Cd ,_ o -f Regulation 6; Part A; MPS Subpart Kb Storag e Tau, s . _ .._PS Ka Regulation 6,. Part A, NSPS Subpart OOOO Not enough information NS PS Subpart OOOOa. igat enough information Regulation B, Part E, MACE Subpart HH Produced Water Storage tank 0 not subject to MALT NH (See regulatory applicability worksheet for detailed analysis) Section 07 Initial. and Periodic Sampling and Testing Requirements For condensate orcrude oil tanks, does the company use the state default emissions factors to estimate emissions? If yes, are the uncontrolled actual or requested emissions for a crude oil tank estimated to be greater than or equal to 20 tons VOC per year OR are the uncontrolled actual or requested emissions for a condensate storage tank estimated to be greater than prequel to 80 tpy? If yes; the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. Does thecompany use a site specific emissions factor to estimate emissions? If yes and if there are flash emissions, are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted (for produced water tanks, a pressurize liquid sample must be analyzed using flash liberation analysis)? This sample should be considered representative which generally means she -specific and collected within one year of the application received date. However; if the facility has not been modified (e.g., no new wells brought on-line(, then it may be appropriate to use an older site -specific sample. If no, the permit will contain an "Initial Compliance" testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 14-03. 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 Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) AIRS Point # Processfl O1 SCC Code Uncontrolled Emissions Pollutant Factor Control% Units PM10 __. 9 lb/1,000 gallons Produced Water throughput PM2.5 OCT 0 lb/1,000 gallons Produced Water throughput SOx kRE(I 0 lb/1,000 gallons Produced Water throughput NOx 0.09 0 lb/1,000 gallons Produced Water throughput VOC 6.24 98 lb/1,000 gallons Produced Water throughput CO 0.40 0 lb/1,000 gallons Produced Water throughput Benzene 0.17 98 lb/1,000 gallons Produced Water throughput Toluene 0.00 98 lb/1,000 gallons Produced Water throughput Ethylbenzene 0.00 98 lb/1,000 gallons Produced Water throughput Xylene 0.00 98 lb/1,000 gallons Produced Water throughput n -Hexane 0.52 98 lb/1,000 gallons Produced Water throughput 224 TMP 000 98 lb/1,000 gallons Produced Water throughput 9 of 18 KAPA\2018\18WE0843,CP3 Storage Tank Regulatory Analysis Worksheet The regulatory requirements below ore determined bored on requested emissions. Colorado Regulation 3 Parts A and B -APEN and Permit Requirements ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this Individual source greater than 2 TPY (Regulation 3, Part A, Section !Lille)? 2. Produced WaterTanks have no grandfathedng provisions 3. Are total facility uncontrolled VOC emissions greater than 5TPY, NOx greater than lO TPY or CO emissions greater than 1011, [Regulation 3, Part B, Section VOA? NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greaterthan lTPY(Regulation 3, Part A, Section ll.D.l.a)? 2. Produced Water Tanks have no grandfathering provisions 3. Are total facility uncontrolled VOC emissions greater than 2 TPY, NOx greater than 5TPY or CO emissions greater than 10 TPY(Regulation 3, Part R, Section ll.D.1)? ScurtNt r.quiru Colorado Regulation 7. Part D. Section I.C-F &G 1. Is this storage tank located in the 8 -hr ozone control area or any ozonenon-attainment area or attainment/maintenance area (Regulation 7, Part 0, Section 111.1)? 2. Is this storage tank located at oil and gas operations that collect, store, or handle hydrocarbon liquids or produced water AND that are located at or upstream of a natural gas processing plant (Regulation 7, Part D, Section I.A.1)? 3. Is thft.orage tank located at a natural gas processing plant (Regulation 7, Part D, Section 16)? 4. Does this storage tank contain condensate? S. Does this storage tank exhibit "Flash" (e.g. storing non -stabilized liquids) emissions (Regulation 7, part D, Section l.G:2)? 6. Are uncontrolled actual emissions of this storage tank equal to or reater than 2tons per year VOC (Regulation 7, Part D, Section 1.0.3.a(ii))7 !Source Requires an APEN. Go to Go to next question Source Requires a permit Source Requires an APEN. G. t. Source Requires a permit Continue - You have indicated th Continue- You have indicated th Storage Tank is not subject to RE Part D, Section l.C.1 —General Requirements for Air PallutionControl Equipment —Prevention of Leakage Part D, Section I.C.2— Emission Estimation Procedures Part D, Section I.D — Emissions Control Requirements Part D, Section I.E—Monitoring Part D, Section I.F— Recordkeeping and Reporting 44*.; Part 0, Section I.G.2- Emissions Control Requirements Part 0, section I.C.l.a and b —General Requirements for Air Pollution Control Equipment — Prevention of Leakage Colorado Regulation 7. Part D. Section II 1. Is the storage tank located at a transmission/storage facility? 2. Is this storage tanks located at an oil and gas exploration and production operation , well production facility', natural gas compressor stations or natural gas processing plare(Regulation 7, Part D, Section LC)? 3. Does this storage tank have a fixed roof(Regulation 7, Part D, Section'LA.20)? 4. Are uncontrolled actual emissions of this storage tank equal to or greater than 2tons per year VOC (Regulation 7, Part D, Section ll.C.1c)? '»tivik Is Uhttut Nttgttlahhsts Part D,Section Provisions for Air Pollution Control Equipment and Prevention of Emissions Part D, Section II.C.1- Emissions Control and Monitoring Provisions Part D, Section II.C.3- Recordkeeping Requirements 5. Doesthe storage tank contain only "stabilized" liquids (Regulation 7, Part 0, Section ll.C.2.6)? Part D, Section I (.C.2 - Capture and Monitoring for Storage Tanks fitted with Air Pollution Control Equipment Isthe controlled storage tank located at a well production facility, natural gas compressorstatlon, or natural gas pro sing plant constructed on or after May1,2020 or located at a facility that was modified on or after May 1, 2020, such 6. that an additional controlled storage vessel is constructed to receive an anticipated increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part D,Sectlon ll.C.4.a.(I)? Continue -You have indicated th Go to the next question -You ha Go to the next question Source is subject to parts of Reg, r 'Source is subject to all provision Is the controlled storage tank located at a well production facility, natural gas compressor station, or natural gas processing plant constructed an or after January 1, 2021or located at a facility that was modified on or after January 1, 7. 2021, such that an additional controlled storage vessel is constructed to receive an anticipated Increase in throughput of hydrocarbon liquids or produced water (Regulation 7, Part 0, Section II.C4.a(iii? • Uths,uticht79aN 1' 5e. ii i l.lT,h-f 40 CFR, Part 60, Subpart Kh. Standards of Performance for Volatile Organic Liquid Storage Vessels 1. Is the Individual storage vessel capacity greater than or equal to 75 cubic meters (ms) (-472 BBLs] (40 CFR 60.110h(a))? 2. Doesthe storage vessel meet the following exemption in 6o.11lb(d)(4)? a. Does the vessel has a design capacity less than or equal to 1,589.874 ms 1'10,000 BBL] used for petroleums. condensate stored, processed, or treated priorto custody transfers as defined in 60.111b7 3. Was this storage vessel constructed, reconstructed, or modified (see definitions 40 CFR, 60.2) after July 23,1984(40 CFRr60.110b[a))? 4. Does thetank meet the definition of"storage vessel"' in 60.111b? 5. Does the storage vessel store a"volatile organic liquid(VOL)"sas defined in 60.1116? 6. Doesthe storage vessel meet arty one of thefollowing additional exemptions: a. Is the storage vessel a pressure vessel designed to operate In excess of 204.9 kPa 1-29.7 psi] and without emissions tothe atmosphere (60.1106(d)(2))?; or b. The design capacity 6 greater than or equal to 151 ms (`950 BBL] and stares a liquid with a maximumtrue vapor pressures less than 3.5 kPa (60.110b(b))?; or c. The design capacity s greater than or equal to 75 Ms 1-472 BBL] but less than 151 ms ("950 BBL] and stores a liquid with a maximum true vapor pressure' lessthan 15.0 kPa(60.110b(b))? Does the storage tank meet either one of the following exemptions from control requirements: a. The design capacity h greater than or equal to 151 ms [-950 BBL] and stores a liquid with a maximumtrue vapor pressure greater than or equal to 3.5 kPa but less than 5.2 kPa?; or b. The design capacity b greaterthan or equal to 75 M' ("An BBL] but less than 1510 1-950 BBL) and stores a liquid with a maximum true vapor pressure greaterthan or equal to 15.0 kPa but less than 27.6 kn. ISicragerat* ISE,.t Noss; Storage Tank is not subject to RE Storage Tank is not subject NSPS 40 CFR. Part 60. Subpart 0000/0000e. Standards of Performance for Crude Oil and Natural Gas Praduction.Transmisslon and Distribution 1. Is this storage vessel located at a facility in the onshore oil and natural gas production segment, natural gas processing segment or natural gas transmission and storage segment of the industry? 2. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) between August 23, 2o11and September 18, 20157 3. Was this storage vessel constructed,reconstructed, or modified (see definitions 40 CFR, 60.2) after September 18, 2015? 4. Are potential VOC emissions' from the individual storage vessel greater than or equal to 6 tons per year? 5. Does this storage vessel meet the definition of "storage vesser2 per 60.5430/60.5430.? 6. Is the storage vessel subject to and controlled in accordance with requirements for storage vessels in 40 CFR Part 60 Subpart Kb or 40 CFR Part 63 Subpart NH? ' Ntut _nouah ittF:.maric . [Note; If a storage vessel Is previously determined to be subject to NSP50000/0000a due to emissions above 6 tans per year VOC on the applicability determination date, It should remain subject to NSP50000/0000a per 60.5365[e[(21/60.5365a(al(2) even if potential VOC emissions drop below 6 tons per year] 40 CFR Part 63. Subpart MALT NH, Oil and Gas Production Facilities 1. Is the storage tank located at an oil and natural gas production facility that meets either of the following criteria: a. A facility that processes, upgrades or stores hydrocarbon liquids' (63.760(a)(2)); OR b. Afacility that processes, upgrades or stores natural gas or. tothe point at which natural gas enters the natural gas transmission and storage source category or b delivered to a final end user' (6.3.760(a)(3))? 2. Is the tank located at a facility that p majors for HAPs7 3. Doesthe tank meet the definition of "storage vessel"' in 63.7617 4. Does the tank meet the definition of"storagevessel with the potentlalfor flash emissions"' per 63.761? 5. Is the tank subject to control requirements under 40 CFR Part 60,5ubpart Kb or Sub art 0000? 'p.ttttucts, stccug tcthl l ontinue - You have indicated th (Yes 'Continue- You have indicated th Subpart A, General provisions per 463.764 (a) Table 2 463.766- Emissions Control Standards 463.773 - Monitoring §63.774 Recordkeeping §63.775 - Reporting PAR Review PAR review Is required If Regulation 7 does not apply AND ifthe tank Is In the non -attainment area. If the tank meets both criteria, then review RACT requirements. Disclaimer rtRm','-'R,a-'"' Storage Tank Is not subject MAC This document assists operators with determining applicability of certain requirements of the Clean Air Act, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particular situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, r any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ ifs implementing regulations, and Air Quality Control Commission regulations, the language of the statute orregulafion will control. The use of non -mandatory language such as"recommend,""may,""should,"and °can,"is intended to describe APCQ interpretations and recommendations. Mandatary terminology such as °must" and "required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. 3 Separator Venting Err' ssians Inventory Section 01- Administrative Information Facility AIRS ID: 123 County 9FE4 Plant Point Section 02 - Equipment Description Details Detailed Emissions Unit Description: Produced naturel gas routed to enc Emission Control Device Description: Requested Overall VOC & HAP Control Efficiency %: Limited Process Parameter Gas meter u Section 03 - Processing Rate Information for Emissions Estimates Primary Emissions - Separator Actual Throughput =:' s. MMscf per year IRequested Permit Limit. Throughput = ;55.1 MMsd per year Potential to Emit (PTE) Throughput = ! 9s.!. MNIscf per year Secondary Emissions - Combustion Devices) for Air Pollution Control Separator Gas Heating Value: Volume of waste gas emitted per BBL liquids throughput: scfh Btu/scf Requested Monthly Throughput= 13.2 MMscf per month Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: ._ MMsd/'r Section 04 - Emissions Factors & Methodologies MW Weight Helium CO2 N2 methane ethane propane isobutane n -butane isopentane n -pentane cyclopentane n -Hexane ryclohexane Other hexanes heptanes m ethylcyclohexane 224-TMP Benzene Toluene Ethylbenzene Xylenes CS+Heavies Total VOC Wt Ib/Ib-mol Displacement Equation Ex=Q*MW*Xx/C 12 of 18 K:\PA\2018\18W E0843:CP3 Separator Venting Emisslons Inventory' Pollutant Pollutant Pollutant Section 05 - Emissions Inventory Separator Venting Uncontrolled (Ib/MMscf) Controlled (Ib/MMscf) Primary Control Device Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Uncontrolled Ib/MMscf (Gas Throughput) Pilot Light Emissions Uncontrolled (Ib/MMBtu) (Waste Heat Combusted) Uncontrolled Ib/MMscf (Pilot Gas Throughput) Emission Factor Source Emission Factor Source Emission Factor Source Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tons/year) (tons/year) Requested Monthly Limits Controlled. (Ibs/month) PM10 PM2.5 Sox NOx VOC CO 0,a` 9.H 0.8 0.3 0.3 3.8 •.8 0.8 OS- 0,8 138 0.1 e..., 0.1 0.1 0,1 :._. 7.4 7.4 7-4 1258 1745.;. 35.0 1748.5 34.97 594 _., __,- 33.73.3-7 333.7 5724 Hazardous Air Pollutants Potential to Emit Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (lbs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene %ylene n -Hexane 224 TMP 10094 202 100,`94 202 _„_75 20978 .__ 10978 220 2310 _...__ E_ 231'_ 40 6450 645_ 229 73575 =_.',; '_,17_ 73575 1472 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B Regulation 7, Part D, Section ILB, F Regulation 7, Part D, Sectiortil.B.2.e (See regulatory applicability worksheet for detailed analysis) Sour�',qu=__ a perrniz 13 of 18 KAPA\2018\18WE0843.CP3 Section 07 - Initial and Periodic Sampling and Testing Requirements Using Gas Throughput to. Monitor Compliance Does the company use site specific emission factors based on a gas sample to estimate emissions? This sample should represent the gas outlet of the equipment covered under this AIRS ID, and should have been collected within one year of the application received date. However, if the facility has not been modified (e.g., no new wells brought on-line), then it may be appropriate to use an older site -specific sample. _ If no, the permit will contain an "Initial Testing Requirement" to collect a site=specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are lessthan or equal to the emissions factors established with this application. Are facility -wide permitted emissions of VOC greater than or equal to 40 tans per year in the ozone nonattainment area OR are emissions greater than or equal to 90 tons per year in the ozone attainment area? If yes, the permit will contain: -An "Initial Testing RequiremenY'to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application. -A "Periodic Testing Requirement" to collect a site -specific gas sample from the equipment being permitted and conduct an emission factor analysis to demonstrate that the emission factors are less than or equal to the emissions factors established with this application on an annual basis. Will the operator have a meter installed and operational upon startup of this point? Yes - If no, the permit will contain a condition that requires the operator to calculate gas throughput using the liquid throughput until the meter is installed and operational (not to exceed 180 days). This condition will use the 'Volume of waste gas emitted per BBL of liquids throughput" (sef/bbl) value in section 03. 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 Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) AIRS Point # Process # SCC Code 003 01 _ .0-001 60 Par. P M10 PM2.5 SOx NOx VOC CO Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Pollutant Uncontrolled Emissions Factor Control % Units `0.. 0 €b114104SCF 1.4 ., 18115'A9C= 0.8 0 lb 4141CP 95,3 0 lb/161838f 2255311 98 lb/0414188F 434 _ ib; f .11083 55-`s. 98 80106105133 7-3.8 98 ib/81181261- 14,3- 98 00/1311153111: 41.6 91 lb/08151863 4?4,5 93 s?'N}13Sfr 0.3 98 4381511815CF 14 of 18 K:\PA\2018\18W E0843.CP3 Separator Venting Regulatory Analysis Worksheet The regulatory requirements below are determined based on requested emissions. Colorado Regulation 3 Parts A and B -APEN and Permit Requirements Source es In tfie'= o.-fos ioaceofArea ATTAINMENT 1. Are uncontrolled actual emissions from any criteria pollutants from this individual source greater than 2 TPY (Regulation 3, Part A, Section 11.0.1.a17 2. Are total facility uncontrolled VOC emissions greater than 5 TPY, NOx greater than 10 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.3)? Ia., have indismad that source is in the Non-Atte.mext are. NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from this individual source greater than 1TPY(Regulation 3, Part A,Section 11.0.1.a)? 2. • Are total facility uncontrolled VOC emissions from the greater than 2 TPY, NOx greater than 5 TPY or CO emissions greater than 10 TPY (Regulation 3, Part B, Section 11.0.2)? Icau ss senoires a aueuit Colorado Regulation 7, Part 0, Section II 1 Was the well newly constructed, hydraulically fractured, ompleted on or after August 1, 2014? ISo...ee is subo.f. Roguiatioaifo.,C.Se- Section II.B.2— General Provisions for Air Pollution Control Equipment Used to Comply with Section II Section ILF - Control of emissions from well production facilities Alternative Emissions Control (Optional Section), a. Is this separator i II d by a back-up or alternate6 t n d (Inot the primary control device) that is not enclosed? ITha fissfss for Das P _sea.._nT Pass EaSacsioit Section II.B.2.e—Alternative emissions control equipment Disclaimer This document assists operators with determining applicability of certain requirements of the Clean AirAct, its implementing regulations, and Air Quality Control Commission regulations. This document is not a rule or regulation, and the analysis it contains may not apply to a particalar situation based upon the individual facts and circumstances. This document does not change or substitute for any law, regulation, or any other legally binding requirement and is not legally enforceable. In the event of any conflict between the language of this document and the language of the Clean Air Act„ its implementing regulations, and Air Quality Control Commission regulations, the language of the statute or regulation will control. The use ofnon-mandatorylanguage such as "recommend," "may,•• °should,"and "can,"is intended to describe APCO interpretations and recommendation. Mandatory terminology such as "must" and 'required" are intended to describe controlling requirements under the terms of the Clean Air Act and Air Quality Control Commission regulations, but this document does not establish legally binding requirements in and of itself. • Source Re Source Re reasttiscar,cis- The contra Hydrocarbon i undo=.ft Erni5sions inventory Section 01 -Administrative Information Facility AIRS ID: Plant Poin Section 02 - Equipment Description Details Detailed Emissions Unit Description: Emission Control Device Description: Is this loadout controlled? Requested Overall VOC & HAP Control Efficiency %: Section 03 - Processing Rate Information far Emissions Estimates Primary Emissions - Hydrocarbon Loadaut Actual Volume Loaded = (Requested Permit Limit Throughput= Potential to Emit (PTE) Volume Loaded = Barrels (bbl) per year Barrels (bbl) per year Requested Monthly Throughput= 53301 Barrels (bbl) per month Secondary Emissions -. Combustion Device(s) Heat content of waste gas = Actual Volume of waste gas emitted per year = Requested Volume of waste gas emitted per year = Actual heat content of waste gas routed to combustion device = Requested heat content of waste gas routed to combustion device = t: Barrels (hbl) per year r, Btu/scf '_11723 scf/year 111770 scf/year Potential to Emit (PTE) heat content of waste gas routed to combustion device= 1.79 L136 MMBTU per year 0 MMBTU per year 201 MMBTU per year Control Device Pilot Fuel Use Rate: Pilot Fuel Gas Heating Value: SC to/scf 0" MMscf/yr 3.0 MMBTU/yr Section 04 - Emissions Factors & Methodologies Does the company use the state default emissions factors to estimate emissions? Does the hydrocarbon liquid loading. operation utilize submerged fill.? Emission Factors Pilot Light Emissions Pollutant VOC Benzene Toluene Ethylbenzene Xylene n -Hexane 224 TMP Pollutant PM10 PM2.5 SOx CO Pollutant PMS0 PM2.. SOx NOx VOC CO Hydrocarbon Loadaut Uncontrolled Controlled (Ib/bbl) (lb/bbl) (Volume Loaded) Control Device (Volume Loaded) Uncontrolled Uncontrolled (Ib/MMBtu) (lb/bbl) (waste heat combusted) (Volume Loaded) 2.410306 Uncontrolled Uncontrolled (Ib/MMBtu) Emission Factor Source Emission Factor Source pb/MMscf) Emission Factor Source (Pilot Gas (Waste Heat Combusted) Throughput) 16 of 18 K:\PA\2018\18W E0843.CP3 'Hydrocarbon Loado t Emissoans Inventory Section OS - Emissions Inventory Criteria Pollutants Potential to Emit Uncontrolled (tons/year) Actual Emissions Uncontrolled Controlled (tons/year) (tons/year) Requested Permit Limits Uncontrolled Controlled (tans/year) - (tons/year) Requested Monthly Limits Controlled (Ibs/month) PM30. PM2.5 SOx NOx VOC CO 0,00 0.00 0.-00 0.00 0.017. 0 0.00 0.60 0.00 0.00 0.00 9 ,,,,u 0.00 0.1,0 0.00 _.O._ 0 i, 31 0.01 OM 0.01 ..�3 7.36 0.15 7.35 0 IS 1717 00 im t0.M C.D4 C '... 0.04 Hazardous Air Pollutants Potential to Emit .Uncontrolled (Ibs/year) Actual Emissions Uncontrolled Controlled (Ibs/year) (Ibs/year) Requested Permit Limits Uncontrolled Controlled (Ibs/year) (Ibs/year) Benzene Toluene Ethylbenzene Xylene n -Hexane 224 IMP 16 0 0 _ 0ii 0 _ 0 J d ., 0 17,17. :0170-. - 225 Section 06 - Regulatory Summary Analysis Regulation 3, Parts A, B >_.a.__ ....,uir_s a permit' Regulation 7 Part D Section II.C.5. (See regulatory applicability worksheet for detailed analysis) `ha hydrocarbon 1lqultta i<admit source le to byect to Regulation 7 Par. P 5e.tion IS.C.5. 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? Oyes, the permit will contain initial and periodic compliance testing in accordance with PS Memo 20-02 Section 08 -Technical Analysis Notes Switching to state default emission factors Section 09 - SCC Coding and Emissions Factors (For Inventory Use Only) AIRS Point # 004 Process # 01 SCC Code 06,001-32 Crude Oil' Sun arge2 Loading Normal Corvine (0-0.64 Uncontrolled Emissions Pollutant Factor Control % Units PM10 0.170 0 lb/1,000 gallons transferred PM2.5 0.031 0 lb/1,000 gallons transferred - SOx 0.00 0 lb/1,000 gallons transferred NOx 3.01 0 lb/1,000 gallons transferred VOC S.6 96 lb/1,000 gallons transferred CO +'_.03 D lb/1;000 gallons transferred Benzene -0.u1 . lb/1,000 gallons transferred Toluene GOO 98 lb/1,000 gallons transferred Ethylbenzene 9:00 98 lb/1,000 gallons transferred Xylene D.3 98 lb/1,000 gallons transferred n -Hexane -3.00 98 lb/1,000 gallons transferred 224 TMP O.O0 98 lb/1,000 gallons transferred 17 of 18 KAPA\2018\18WE0843.CP3 Hydrocarbon Load°. Regulatory Analysis Worksheet The regulatory requirements below ore determined based on requested emissions and throughput. Colorado Regulation 3 Parts A and B - APED and Permit Requirements ,v In Ma nun.tt.nnent Ara ATTAINMEND 1. Are uncontrolled actual emissions from any criteria pollutants torn this individual source greater than 2TPy(Regulation 3, Part A, Section ll.D.1.a)? Is the loadout located at an exploration and production site (e.g., well pad)'Regulation 3, Part %Section 3. Is the loadutoperanon loading less Nan 10,000 gallon (DR Sao) of crude dl per day m an annual average..? Is the loadwtweratian loading less than 6,750 bbls per year ofcondensate via splash fill? 5. Is the loadout operation 'mans less than 16,303 Ells per year &condensate via submerged fill procedure? 6. Are total facility uncontrolled VOL emissions greater t an s TPY, PCs greater than la TPY or CO emissions greater than 10 TPY iRegulation 3, Part s, SectionlL0.31? NON -ATTAINMENT 1. Are uncontrolled emissions from any criteria pollutants from Ws individual source greater than 1 TPY (Regulation 3, PartA, Section lln.l.ali 2. Odle loadoutlocuhd atan...radon aM praductiond.(e.g., well Pad)(Regnlation 3, Part 0, Secb'm 11.0.1.11? Is the loadout on loading iess than 16,000 gallons (233 Bets) of crude dl per day annual average basis. 6. Is the loadout operation loading less than 6050 hbhs per year ofcolic...via splash DIX an 5. Is the loadout operation loading less OB bbls per year onden asubmeed fill procedure] 6. Pre total facility uncontrolled VOC emissions from the grater Nap 11" NOR greater than 5 Tin( or emissions greater than to TRY (Regulation 3, Porte, Sect ion ll.D.2 Colorado Regulation T Part 0Sechon %CS,. 1. Is disccanderw tank hydroaabon liquids loadout lomted at well production facility, natural natural gas processing plant? 2. Does the facility have a throughput&hydrocarbon liquids loadout to transport vehicles greater Manor equal to 5`000 barreis? IT.it m Section Il.e.s.a.li'-compliance Schedule Section.a.11ll- Operation without Venting Secdons.a.Ihiil -Lmtlwt Equipment Operation and Maintenance Secdon s ahivl- Loadoutobser atlns and OperatorTnining section S.a.lvl - Records Section II.Gs.a.ivi)-Requiremerrz far Nr Paludon Control Equipment Disclaimer This document asstsh operators with determining applicability or certain requirements or the Clean Air Act, its Implementing regulations, and Air Quality Control Commission regulations. This document Is not e rule or regulation, and Me anahsis it contains may not apply to a pellicles situation based upon the individual foots and circumstances. This document does not change or substitute for whim, regulation, or eny otherogelly binding egwroment ands not legally enforceable. In thee..orany conflict between the language of this document end the hoguege M the Clean Air Act„ its lmpnerentingregulations, and Air Quality Cock. Commission regulations, the language at the statute or regulation will conhM The use d nmmandatory language such as hecwnmerich -may.-"slmWd- and Men,-is',facial is describe APCQ inia-petatons and recommendations. Mandatory temAmlcgy mob as -must' end',area' are intended to doscribe controlling requirements under the taros Mere Clean Air Act and Air Quality Control Commission regulations, MR this document dams oaf establish legally binding requirements in and at itself. Go to no o then. question Co to next question Go to next question Go to next question The loadout requires a permit Go to nextrgn.tum. Source isz o Regulation) Part 0Sectin Il.C5. CDPHE Condensate Storage Tank(s) APEN Form APCD-205 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 locks 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: 1 8WE0843 AIRS ID Number: 123 / 9FE4 /001 Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Mustang 14-26 Production Facility (COGCC# 450210) Site Location: 40.279919, -104.413753 NWSW, Sec 26, T4N, R63W Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Denver, CO 80202 Site Location County: Weld NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Address2: Alisson Soehner (303) 803-1752 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. '28289 COLORADO on� x . Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 001 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ 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 ❑ MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 ✓❑ Change permit limit ❑ Transfer of ownership4 ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will 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 a Notes: Adjusting permitted throughput using existing 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: Company equipment Identification No. (optional): For existing sources, operation began on: Tank battery used for condensate storage CND Tank Battery 04/27/2018 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 Storage tank(s)located at: i] Exploration a Production (E&P) site days/week 52 weeks/year ❑ Midstream or Downstream (non E&P) site Will this equipment be operated in any NAAQS nonattainment area? Yes No IS ■ Are Flash Emissions anticipated from these storage tanks? GI Yes ■ No Is the actual annual average hydrocarbon liquid throughput ≥ 500 bbl/day? Yes No ■ p If "yes", identify the stock tank gas -to -oil ratio: m3/titer Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)• 805 series rules? If so, submit Form APCD-105. Yes No p Are you requesting ≥ 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions a 6 ton/yr (per storage tank)? Yes No D GC COLORADO ilrylartmavo al 1,1, HWeb b [n.nmm,n[ ❑ Upward ❑ Horizontal Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 001 Section 4 - Storage Tank(s) Information Condensate Throughput: Actual Annual Amount (bbi/year) 62,415 Requested Annual Permit Limits (bbUyear) 62,415 From what year is the actual annual amount? 2019 Average API gravity of sales oil: 55.8 degrees ❑ Internal floating roof Tank design: ❑r Fixed roof RVP of sales oil: 7.4 ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbi) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) CNDTK01-03 Three (3) 500 -bbl 1,500 2/2018 4/2018 Wells Serviced by this Storage Tank or Tank Battery& (MP Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 44700 Mustang D14-26-25XRLNB ■ ■ El ■ 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. & The EftP 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) 40.279919,-104.413753 ❑ 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 ID No. Discharge Height Above Ground Level (Feet) Temp. (°F) Flow Rate (ACFM) Velocity (ft/sec) ECD-01 -35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) ❑ Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): 96 Interior stack width (inches): Interior stack depth (inches): ®COLORADO DeportmuINb nuawar M./N b Fnr„enm.n, Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 001 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. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Make/Model: Requested Control Efficiency: % VRU Downtime or Bypassed (emissions vented): % ❑ Combustion Device: Pollutants Controlled: HAPs, VOC Rating: 1.27 MMBtu/hr Type: Enclosed Combustor Make/Model: One (1) Crimson CE -1000 Requested Control Efficiency: 9$ % Manufacturer Guaranteed Control Efficiency: 99 % Minimum Temperature: 500 Waste Gas Heat Content: 2,752 Btu/scf Constant Pilot Light: Ei Yes ❑ No Pilot Burner Rating: N/A MMBtu/hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: Description: Control Efficiency Requested: % Section 7 - Gas/Liquids Separation Technology Information (MP Sites Only) What is the pressure of the final separator vessel prior to discharge to the storage tank(s)? —75 psig Describe the separation process between the well and the storage tanks: The on -site separator separates condensate, water and gas. Condensate is then routed to the three (3) storage tanks on site until it is trucked away. lee COLORADO Depab eras Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 001 Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form7. Is any emission control equipment or practice used to reduce emissions? ❑✓ 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): Pollutant Control Equipment Description Collection Efficiency of of total emissions captured by control equipment) Control Efficiency (X reduction of captured emissions) V0C ECD 100 98 NOx CO HAPs ECD too 98 Other: From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor? Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (�"42� Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions8 (tans/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) VOC 6.8528 Ib/bbl Permit 12 213.86 4.28 213.86 4.28 NOx 0.068 Ib/MMBtu AP -42 0.38 0.38 0.38 0.38 CO 0.310 Ib/MMBtu AP -42 1.73 1.73 1.73 1.73 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. 7 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 pollutants (e.g. HAP - hazardous air pollutant) equal to or greater than 250 lbs/year? Ei Yes ❑ No If yes, use the following table to report the non -criteria pollutant (HAP) emissions from source: Chemical Name Chemical Abstract Service (CAS) Number Emission Factor? Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (lbs/year) Controlled Emissions8 Ps/year) Benzene 71432 0.0437 lb/bbl Permit 12 2.728 56 Toluene 108883 00415 Ibrobl Perm it 12 2,590 52 Ethylbenzene 100414 0 0059 lb/bbl Permit 12 368 B Xylene 1330207 00127 Ibrobl Permit 12 793 16 n -Hexane 110543 02831 lb/bbl Permit 12 17.670 354 2,2,4-Trimethylpentane 540841 0.0022 lb/bbl Permit 12 De Minimis De Minimis 7 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 Depaement NI..6 Env,mnmwn. Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 001 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. 3/23/2020 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: ❑� Draft permit prior to issuance 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: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Small Business Assistance Program (303)692-3175 OR (303) 692-3148 APCD Main Phone Number (303)692-3150 > COLORADO be;artmem a Punic He.. 5 temtommnx CDPHE Produced Water Storage Tank(s) APEN Form APCD-207 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 produced water 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, condensate storage tanks, hydrocarbon liquid loading, 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 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: 1 8WE0843 AIRS ID Number: 123 / 9FE4 /002 Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Mustang 14-26 Production Facility (COGCC# 450210) Site Location: 40.279919,-104.413753 NWSW, Sec 26, T4N, R63W Mailing Address: (Include Zip Code) 410 17th Street, Suite 1400 Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Addressz: asoehner@bonanzacrk.com 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. 428290 g® COLORADO D.prbnmr at Public lion. r e r.v.rr..m Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 002 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source ❑ Request coverage under traditional construction permit ❑ Request coverage under a General Permit ❑ GP05 ❑ 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- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change in equipment ❑ Change company name3 ✓❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) OR - APEN submittal for update only (Note blank APENs will 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 is Notes: Adjusting permitted throughput using existing 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: Tank to store produced Water Company equipment Identification No. (optional): PWT-01 For existing sources, operation began on: 04/27/2018 For new or reconstructed sources, the projected start-up date is: Normal Hours of Source Operation: 24 hours/day 7 Storage tank(s) located at: days/week 52 weeks/year i] Exploration Et Production (EEtP) site ❑ Midstream or Downstream (non EEtP) site Will this equipment be operated in any NAAQS nonattainment area? p Yes ■ No Are Flash Emissions anticipated from these storage tanks? 0 Yes ■ No Are these storage tanks located at a commercial facility that accepts oil production• wastewater for processing? Yes No p Do these storage tanks contain less than 1% by volume crude oil on an annual average basis? O Yes ❑ No Are these storage tanks subject to Colorado Oil and Gas Conservation Commission (COGCC)• 805 series rules? If so, submit Form APCD-105. Yes No O Are you requesting a 6 ton/yr VOC emissions (per storage tank), or are uncontrolled actual• emissions ≥ 6 ton/yr (per storage tank)? Yes No p hiplieja, COLORADO of grbtda.aK �ifinn 6 Fnviemment Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 002 Section 4 - Storage Tank(s) Information IProduced Water Throughput: Actual Annual Amount (bbUyear) 22,685 Requested Annual Permit Limits (bbUyear) 68,055 From what year is the actual annual amount? Tank design: ✓❑ Fixed roof 2019 ❑ Internal floating roof ❑ External floating roof Storage Tank ID # of Liquid Manifold Storage Vessels in Storage Tank Total Volume of Storage Tank (bbl) Installation Date of Most Recent Storage Vessel in Storage Tank (month/year) Date of First Production (month/year) PINT -01 One (1) 500 -bbl 500 2/2018 4/2018 Wells Serviced by this Storage Tank or Tank Battery° (CEP Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 44700 Mustang D14-26-25XRLNB ■ ■ ID IN 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. ° The EEtP 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) 40.279919/-104.413753 ❑ 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 ID No. Discharge Height Above Ground Level (Feet) Temp. en Flow Rate (ACFM) Velocity (ft/sec) ECD-01 —35 500 TBD TBD Indicate the direction of the stack outlet: (check one) Q Upward ❑ Horizontal ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) 0 Circular Interior stack diameter (inches): 96 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): COLORADO Dep...ew. N tvWr x.au Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 002 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. Vapor ❑ Recovery Unit (VRU): Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed (emissions vented): Make/Model: ❑ Combustion Device: Pollutants Controlled: HAPs, VOC Rating: 0.42 Type: Enclosed Combustor MMBtu / hr Make/Model: Requested Control Efficiency: 98 % Manufacturer Guaranteed Control Efficiency: gg % Minimum Temperature: N/A One (1) Crimson CE -1000 Waste Gas Heat Content: Constant Pilot Light: ❑ Yes No Pilot Burner Rating: 1,496 N/A Btu/scf MMBtu / hr ❑ Closed Loop System Description of the closed loop system: ❑ Other: Pollutants Controlled: 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)? -75 psig Describe the separation process between the well and the storage tanks: The on -site separator separates condensate, water and gas. Produced water is then routed to the one (1) storage tank on site. COLORADO Nyetunem.hibim ReaMbElmmonm. Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 002 Section 8 - Criteria Pollutant Emissions Information Attach all emissions calculations and emission factor documentation to this APEN form7. Is any emission control equipment or practice used to reduce emissions? E3 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): Pollutant Control Equipment Description Collection Efficiency (% of total emissions captured by control equipment) Control Efficiency (% reduction of captured emissions) VOC - ECD 100 98 NOx CO HAPs ECD 100 98 Other: From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor7 Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source ('� 42� Mfg., etc.) Uncontrolled Emissions (tans/year) Controlled Emissions$ (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) VOC 0.2620 Ibfbbl State Defatult 2.97 0.06 8.92 0.18 NO. 0 0037 lb/bbl State Defatult 0 04 0.04 0.13 0.13 CO 0.0167 lb/bbl State Defatult 0.19 0.19 0.57 0.57 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. 7 Attach produced water 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 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 Name Chemical Abstract Service (CAS) Number Emission Factor7 Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (lbs/year) Controlled Emissions8 - Ohs/year) Benzene 71432 0.0070 lb/bbl State Default De Minimis De Minimis Toluene 108883 N/A N/A N/A N/A N/A Ethylbenzene 100414 N/A N/A N/A N/A N/A Xylene 1330207 N/A N/A N/A N/A N/A n -Hexane 110543 0.0220 lb/bbl State Default 500 10 2,2,4-Trimethytpentane 540841 NIA N/A N/A N/A N/A ❑✓ Yes ❑ No 7 Attach produced water 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. le© COLORADO Otpartment a wm. Re.. b [n..mnmew Permit Number: 1 8WE0843 AIRS ID Number: 123 i 9FE4 / 002 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 GP05 or GP08, I further certify that this source is and will be operated in full compliance with each condition of the applicable General Permit. 3/23/2020 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: Draft permit prior to issuance 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: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment Small Business Assistance Program (303)692-3175 OR (303)692-3148 APCD Main Phone Number (303) 692-3150 COLORADO neF.n,... at P aK Ma.6 Fnv.ronme... Gas Venting APEN - Form APCD-211 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 wilt 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 gas venting only. Gas venting includes emissions from gas/liquid separators, well head casing, pneumatic pumps, blowdown events, among other events. 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, hydrocarbon liquid loading, 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: 1 8WE0843 AIRS ID Number: 123 / 9FE4 /003 Section 1 - Administrative Information Company Name': Bonanza Creek Energy Operating Company, LLC Site Name: Mustang 14-26 Production Facility (COGCC# 450210) Site Location: 40.279919, -104.413753 NWSW, Sec 26, T4N R63W Mailing Address: 410 17th Street, Suite 1400 (Include Zip Code) Site Location County: Weld NAICS or SIC Code: 1311 Denver, CO 80202 Contact Person: Alisson Soehner Phone Number: (303) 803-1752 E -Mail Address2: asoehner@bonanzacrk.com ' 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. 428292 ea COLORADO � F 6 EnrVmrme. Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 003 Section 2 - Requested Action ❑ NEW permit OR newly -reported emission source -OR- Q MODIFICATION to existing permit (check each box below that applies) ❑ Change fuel or equipment ❑ Change company name3 ❑ Add point to existing permit O Change permit limit ❑ Transfer of ownership° ❑ Other (describe below) -OR - . ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info & Notes: Adjusting permitted throughput using existing emission factors. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. ° 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: gas from separator. Enclosed combustor to control Company equipment Identification No. (optional): For existing sources, operation began on: ECD-01 04/27/2018 For new, modified, or reconstructed sources, the projected start-up date is: 0 Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: hours/day Will this equipment be operated in any NAAQS nonattainment area? Is this equipment located at a stationary source that is considered a Major Source of (HAP) Emissions? Is this equipment subject to Colorado Regulation No. 7, Section XVII.G? days/week weeks/year ❑Q Yes ❑ Yes ✓❑ Yes ❑ No (] No ❑ No irs LCOLORADO awn. e rsm Haa1tA i n�.wnmi Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 003 Section 4 - Process Equipment Information ❑✓ Gas/Liquid Separator ❑ Well Head Casing ❑ Pneumatic Pump Make: Model: ❑ Compressor Rod Packing Make: Model: ❑ Blowdown Events # of Events/year: ❑ Other Description: Serial #: # of Pistons: Volume per event: Capacity: gal/min Leak Rate: Scf/hr/pist MMscf/event If you are requesting uncontrolled VOC emissions greater than 100 tpy for a gas/liquid separator, you must use Gas Venting as a process parameter. Are requested uncontrolled VOC emissions greater than 100 tpy? ❑Q Yes Gas Venting Process Parameterss: Liquid Throughput Process Parameterss: Vented Gas Properties: ❑ No Vent Gas Heating Value: 1,402 BTU/SCF Requested: 155.06 MMSCF/year Actual: 155.06 MMSCF/year -OR- Requested: bbl/year Actual: bbl/year Molecular Weight: 24.5 ' VOC (Weight %) 34.8741 Benzene (Weight %) 0.1006 Toluene (Weight %) 0.1094 Ethylbenzene (Weight %) 0.0230 Xylene (Weight %) 0.0643 n -Hexane (Weight %) 0.7337 2,2,4-Trimethylpentane (Weight %) 0.0004 Additional Required Documentation: El Attach a representative gas analysis (including BTEX ft n -Hexane, temperature, and pressure) Attach a representative pressurized extended liquids analysis (including BTEX 8 n -Hexane, temperature, and pressure) 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. COLORADO u.wRmmdd w.we Heath Lnrrtenmmt Q Upward ❑ Horizontal Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 003 Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.279919,-104.413753 ❑ 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. Orator Stack D Ho. Discharge Height Above Ground Level Terms. r}7 Flortir Mate r MI Velocity tftlset) ECD-01 —35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑ Downward ❑ Other (describe): ❑ Upward with obstructing raincap Indicate the stack opening and size: (check one) Circular Interior stack diameter (inches): 96 ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other (describe): 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 . ❑ VRU: Pollutants Controlled: Size: Requested Control Efficiency: VRU Downtime or Bypassed: Make/Model: % ❑ Combustion Device: Pollutants Controlled: VOC, HAPs Rating: 24.82 MMBtu / hr Type: Enclosed Combustor Make/Model: One (1) Crimson CE -1000 Requested Control Efficiency: , 98 % Manufacturer Guaranteed Control Efficiency: 99 % Minimum Temperature: N/A Waste Gas Heat Content: Constant Pilot Light: ❑ Yes ❑✓ No Pilot burner Rating: 1,402 N/A Btu/scf MMBtu / hr El Other: Pollutants Controlled: Description: Requested Control Efficiency: S COLORADO �ne un.�wnmem Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE'4 / 003 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? 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): Pollutant Control Equipment Description Collection Efficiency O4 of total emissions captured by control equipment) Control Efficiency (% reduction of captured emissions) PM SO. NO. CO VOC ECD 100 98 HAPs ECD 100 98 Other: From what year is the following reported actual annual emissions data? 2019 Use the following table to report the criteria pollutant emissions from source: Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (2r Mfg., etc.) Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM 40 0 ug/L AP -42 0.59 0.59 0.59 0.59 SOX <0.0001 Ib/MMBtu AP -42 <0.001 <0.001 <0.001 <0.001 NO. 0.068 Ib/MMBtu AP -42 644 6.44 6.44 644 CO 0.310 Ib/MMBtu AP -42 33.71 33.71 33.71 33.71 VOC 22.553.1 Ib/MMscf Permit 12 1.748.58 34.98 1]48.58 34.98 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. Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria 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 Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions Ohs/year) Controlled Emissions6 (lbs/year) Benzene 71432 65_1 IbIMMscf Permit 12 10,090 202 Toluene 108883 70.7 IbIMMscf Permit 12 10.972 220 Ethylbenzene 100414 14.9 Ib/MMscf Permit 12 2,308 48 Xylene 1330207 41 6 Ib/MMscf Permit 12 6,448 130 n -Hexane 110543 474.5 Ib/MMscf Permit 12 73.576 1,472 2,2,4-Trimethylpentane 540841 0.3 Ib/MMscf Permit 12 De Minimis De Minimis Other: ✓❑ Yes ❑ No 6 Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, provide projected emissions. SO Depsnatem al COLORADO war Heekb 6 Enr rmmmi Permit Number: 1 8WE0843 AIRS ID Number: 123 / 9FE4 / 003 Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true, and correct. 3/23/2020 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: ❑ Draft permit prior to issuance El 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 to: For more information or assistance call: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Small Business Assistance Program (303) 692-3175 OR (303)692-3148 APCD Main Phone Number Make check payable to: (303)692-3150 Colorado Department of Public Health and Environment s� COLORADO HHmn� IU b Fronnmmt Hydrocarbon Liquid Loading APEN Form APCD-208 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 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-200) 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: 18WE0843 AIRS ID Number: 123 / 9FE4 /004 Section 1 - Administrative Information Company Name: Bonanza Creek Energy Operating Company, LLC Site Name: Mustang 14-26 Production Facility (COGCC# 450210) Site Location Site Location: 40.279919, -104.413753 County: Weld NWSW, Sec 26, T4N, R63W Mailing Address: (include zip code) 410 17th Street, Suite 1400 Denver, CO 80202 NAICS or SIC Code: 1311 Contact Person: Phone Number: E -Mail Address2: Alisson Soehner (303) 803-1752 asoehner@bonanzacrk.com 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. 428291 ise COLORADO annK XdWpU 6Enr.ranm!nl Permit Number: 18WE0843 AIRS ID Number: 123 /9FE4/004 Section 2 - Requested Action ❑ NEW perrnit OR newly -reported emission source ❑ Request coverage under construction permit ❑ 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) ❑ Change fuel or equipment ❑ Change company name3 ❑ Change permit limit ❑ Transfer of ownership' ❑ Other (describe below) -OR - ❑ APEN submittal for update only (Note blank APENs will not be accepted) - ADDITIONAL PERMIT ACTIONS - ❑ Limit Hazardous Air Pollutants (HAPs) with a federally -enforceable limit on Potential To Emit (PTE) Additional Info Ii Notes: Adjusting permitted throughput using existing emission factors. 3 For company name change, a completed Company Name Change Certification Form (Form APCD-106) must be submitted. ' 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: Loadout to tank truck of produced condensate Company equipment Identification No. (optional): L-1 For existing sources, operation began on: 04/27/2018 For new or reconstructed sources, the projected start-up date is: Will this equipment be operated in any NAAQS nonattainment area? Yes No O ■ Is this equipment located at a stationary source that is considered a Major Source of (HAP) emissions? Yes No ■ Eil Does this source load gasoline into transport vehicles? Yes No ■ O Is this source located at an oil and gas exploration and production site? Yes No O ■ If yes: Does this source load less than 10,000 gallons of crude oil per day on an annual average? Yes No O ■ Does this source splash fill less than 6,750 bbl of condensate per year? Yes No O ■ Does this source submerge fill less than 16,308 bbl of condensate per year? Yes No ■ O COLORADO �nDeportment 6 e.��.on�,,,.r� Permit Number: 18WE0843 AIRS ID Number: 123 /9FE4/004 Section 4 - Process Equipment Information Product Loaded: ❑✓ Condensate ❑ Crude Oil ❑ Other: If this APEN is being filed for vapors displaced from cargo carrier, complete the following: Requested Volume Loaded5: 62,415 bbl/year Actual Volume Loaded: This product is loaded from tanks at this faci ity into: Tank Trucks (e.g. "rail tank cars" or "tank trucks") 62,415 bbl/year If site specific emission factor is used to calculate emissions, complete the following: Saturation Factor: N/A Average temperature of bulk liquid loading: N/A -F True Vapor Pressure: N/A Psia @ 60 'F Molecular weight of displaced vapors: N,/ ^ 1 lb/lb mol If this APEN is being filed for vapors displaced from pressurized loading lines, complete the following: Requested Volume Loaded5: bbl/year Actual Volume Loaded: bbl/year Product Density: lb/ft' Load Line Volume: ft'/truckload Vapor Recovery Line Volume: ft3/truckload 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. Section 5 - Geographical/Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.279919,-104.413753 ❑ 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 ID No. Discharge Height Above Ground Level (Feet' . Temp. en Flow Rate (ACFM) Velocity (ft/ ) ECD-01 -35 500 TBD TBD Indicate the direction of the stack outlet: (check one) ❑✓ Upward ❑ Horizontal ❑ Downward ❑ Other (describe): Indicate the stack opening and size: (check one) Q Circular ❑ Square/rectangle ❑ Other (describe): ❑ Upward with obstructing raincap Interior stack diameter (inches): 96 Interior stack width (inches): Interior stack depth (inches): ;SC COLORADO Devertmani xwusamulanm.,n Permit Number: 18WE0843 AIRS ID Number: 123 / 9FE4 / 004 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. J❑ Loading occurs using a vapor balance system: Requested Control Efficiency: too % • ❑ Combustion J Device: Used for control of: voC, HAP Rating: 0.04 MMBtu / hr Type: Enclosed Combustor Make/Model: Crimson CE 1000 Requested Control Efficiency: 98 % Manufacturer Guaranteed Control Efficiency: 99 % Minimum Temperature: N/A 'F Waste Gas Heat Content: 2,290 Btu/scf Constant Pilot Light: ❑ Yes (] No Pilot Burner Rating: NiA MMBtu/hr ❑ Other: Pollutants Controlled: 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? Ej Yes ❑ No If yes, describe the control equipment AND state the collection and control efficiencies (report the overall, or alues if multiple emission control methods were identified in Section 6): Pollutant Control Equipment Description Collection Efficiency (% of total emissions captured by control equipment) Control Efficiency (% reduction of captured emissions) PM SO. NO. CO VOC ECD 100 98 HAPs ECD 100 98 Other: 0 Using State Emission Factors (Required for GP07) VOC 0 Condensate 0.236 Lbs/BBL ❑ Crude 0.104 Lbs/BBL Benzene n -Hexane 0.00041 Lbs/BBL 0.0036 Lbs/BBL 0.00018 Lbs/BBL 0.0016 Lbs/BBL From what year is the following reported actual annual emissions data? 2019 wing table to report the criteria pollutant emissions from source: Pollutant Emission Factor Actual Annual Emissions Requested Annual Permit Emission Limit(s)5 Uncontrolled Basis Units Source (AP et M fg., ) Uncontrolled Emissions (tons/year) Controlled Emissions6 (tons/year) Uncontrolled Emissions (tons/year) Controlled Emissions (tons/year) PM 40 ug/L AP -42 0.001 0.001 0,001 0-001 SOx 0.00025 Ib/MMBtu AP -42 <0.001 <0.001 <0.001 <0.001 NO. 0.068 IblMMBtu AP -42 0.009 0.009 0.009 0.009 CO 0.310 Ib/MMBtu AP -42 0.040 0.040 0.040 0.040 VOC 0.236 lb/bbl State Default 7.36 0.150 7.36 0.150 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. Ank COLORADO law ,==. Permit Number: 18WE0843 AIRS ID Number: 123 /9FE4/004 Section 8 - Non -Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non -criteria 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 Name Chemical Abstract Service (CAS) Number Emission Factor Actual Annual Emissions Uncontrolled Basis Units Source (AP -42, Mfg., etc.) Uncontrolled Emissions (lbslyear) Controlled Emissionsb (Ibs/year) Benzene 71432 0 00041 lb/bbl State Default De Minimis De Minimis Toluene 108883 N/A N/A N/A N/A N/A Ethylbenzene 100414 N/A N/A N/A N/A N/A Xylene 1330207 N/A N/A N/A N/A N/A n -Hexane 110543 0 0036 lb/bbl State Default De Minimis De Minimis 2,2,4-Trimethylpentane 540841 N/A N/A N/A N/A N/A Other: Yes ❑ No 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. fu 3/23/2020 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: Draft permit prior to issuance QQ 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 registration fee of $312.50, if applicable, to: Colorado Department of Public Health and Environment Air Pollution Control Division APCD-SS-B 1 4300 Cherry Creek Drive South Denver, CO 80246-1530 Make check payable to: Colorado Department of Public Health and Environment For more information or assistance call: Small Business Assistance Program (303)692-3175 OR (303) 692-3148 APCD Main Phone Number (303) 692-3150 O COLORADO DeW...nent. NWIr NW tM 6 Ereman..Nnt Hello