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Home My WebLink About20162165.tiffCOLORADO Department of Public Health fl Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 June 28, 2016 Dear Sir or Madam: On June 30, 2016, the Air Pollution Control Division will begin a 30 -day public notice period for Bonanza Creek Energy Operating Company, LLC - State Antelope CPF 0-1 Production Facility. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure " I 4300 Cherry Creek Drive S.. Denver, CO 80246-1530 P 303-692-2000 www.colorado.govicdphe John W. Hickenlooper, Governor Larry Wolk. MD, MSPH, Executive Director and Chief Medical Officer 2016-2165 -7/IL/(G9 --7/r /lCo Air Pollution Control Division Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company, LLC - State Antelope CPF O-1 Production Facility - Weld County Notice Period Begins: June 30, 2016 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company, LLC Facility: State Antelope CPF O-1 Production Facility Oil and gas well production facility SWSE Section 1, T5N, R62W Weld County The proposed project or activity is as follows: Applicant proposes central processing facility include dehydrator, condensate tanks, slop tanks which hold compressor knockout liquids and sales oil reject liquids, Produced water tanks, a low-pressure separator and vapor recovery tower, and hydrocarbon liquid loadout. 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 15WE1000 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Christian Lesniak Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-61 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us G 91O4n09 STATE OF COLORADO OLORADO DEFARTME l OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO: 15WE1000 Issuance 1 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company, LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the State Antelope CPF O-1 Production Facility, located in the SWSE Section 1, Township 5N, Range 62W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Point Description DEHY-01 004 One (1) natural gas dehydration system using triethylene glycol (Make, Model, Serial Number To Be Determined), design rated at 12 mmscf per day, consisting of: one (1) natural gas fired glycol regenerator boiler, rated at 0.50 MMBtu/hr; Two (2) gas -driven Kimray 21015 PV glycol recirculation pumps with a glycol recirculation rate of 3.5 (gal/min). Only one Kimray gas -glycol pump will be operated at any given time. The second Kimray gas - glycol pump serves as a back-up only. This unit is equipped with a flash tank, reboiler and still vent. Stripping gas is not used. Emissions from the still vent are routed to an air-cooled condenser and then to a flare with a minimum control efficiency of 95%. Emissions from the flash tank are 100% recycled to the sales gas line or to the fuel gas system. CNDTK-01 005 Ten (10) above ground 500 bbl atmospheric condensate storage tanks. Tanks are controlled by enclosed combustor(s) with 95% control efficiency. SLOP -01 006 One (1) above ground 500 bbl slop tank for storage of compressor condensate dropout and sales oil reject. Additionally, sales gas is used to push compressor dropout into the slop tank and emitted in the process. Tank is controlled by enclosed combustor(s) with 95% control efficiency. PWT-01 007 Three (3) above ground 500 bbl produced water storage tanks. Tanks are controlled by enclosed combustor(s) with 95% control efficiency. AIRS ID: 123/9DFD Page 1 of 18 Health and Environment r Pollution Control Division Facility Equipment ID AIRS Point Description LPGFL 008 One low-pressure separator controlled by one enclosed combustor during VRU downtime. Combustor has a minimum control efficiency of 95%. L-01 009 Hydrocarbon Loadout to Tanker Trucks THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation or issuance of this permit, whichever comes later, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (Hi) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days after issuance of permit. • manufacturer • model number • serial number AIRS ID: 123/9DFD Page 2 of 18 ene' f P IictHealth and Environment Air Pollution Control Division This informatiodtbalPbe deft/di-the t € tiq MStartul ubmitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility Equipment ID AIRS Point Process Tons per Year Emission Type NO, VOC CO DEHY-01 004 2.7 Point CNDTK-01 005 25.2 Point SLOP -01 006 1 — Tank Liquids 0.7 Point 2 — Blowcase Gas 0.2 Point PWT-01 007 0.4 Point LPGFL 008 1.4 35.8 6.2 Point L-01 009 8.6 Point See "Notes to Permit Holder" for information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit (Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID AIRS ID: 123/9DFD Page 3 of 18 Health and Environment it Pollution Control Division DEHY-01 "_ ncl "" '°(s) VOC, HAPs CNDTK-01 005 Enclosed Flare(s) VOC, HAPs SLOP -01 006 Enclosed Flare(s) VOC, HAPs PWT-01 007 Enclosed Flare(s) VOC, HAPs LPGFL 008 Enclosed Flare(s) VOC, HAPs L-01 009 Enclosed Flare(s) VOC, HAPs 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. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility Equipment ID AIRS Point Process Parameter Annual Limit DEHY-01 004 Condensate Throughput 4380 MMSCF CNDTK-01 005 Condensate Throughput 1742495 BBL SLOP -01 006 Process 1 - Condensate Throughput 13309 BBL Process 2 — Sales Gas Throughput 0.397 MMSCF PWT-01 007 Produced Water Throughput 1121280 BBL LPGFL 008 Gas Vented from Separator 17.14 MMSCF L-01 009 Oil Loaded 1742776 BBL Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. Compliance with the annual throughput limit for AIRS Point 006, Process 2 — Sales Gas Throughput shall be determined by multiplying the condensate throughput measured for process 1 — Condensate Throughput by the gas -to -oil factor found under Point 006 in the Notes to Permit Holder section of this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVI1.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) AIRS ID: 123/9DFD Page 4 of 18 f P$lic°Health and Environment tir Pollution Control Division 12. This source us dt tee the bciorareci,txismeitts of R '-' uiation No. 2. (State only enforceable) 13. Point 004: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 14. Point 004: This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XII.H. Beginning May 1, 2005, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XII. 15. Point 004: This equipment is subject to the control requirements for glycol natural gas dehydrators under Regulation No. 7, Section XVII.D (State only enforceable). Beginning May 1, 2008, uncontrolled actual emissions of volatile organic compounds from the still vent and vent from any gas -condensate -glycol (GCG) separator (flash separator or flash tank), if present, shall be reduced by an average of at least 90 percent through the use of air pollution control equipment. This source shall comply with all applicable general provisions of Regulation 7, Section XVII. 16. Point 004: This source is subject to the requirements of 40 CFR, Part 63, Subpart HH - National Emission Standards for Hazardous Air Pollutants for Source Categories from Oil and Natural Gas Production Facilities including, but not limited to, the following: • §63.764 - General Standards o §Fj3.764 (e)(1) -The owner or operator is exempt from the requirements of paragraph (d) of this section if the criteria listed in paragraph (e)(1)(i) or (ii) of this section are met, except that the records of the determination of these criteria must be maintained as required in §63.774(d)(1). §63.764 (e)(1)(ii) — The actual average emissions of benzene from the glycol dehydration unit process vent to the atmosphere are less than 0.90 megagram per year, as determined by the procedures specified in §63.772(b)(2) of this subpart. §63.772 Test Methods, Compliance Procedures and Compliance Demonstration o §63.772(b) - Determination of glycol dehydration unit flowrate or benzene emissions. The procedures of this paragraph shall be used by an owner or operator to determine glycol dehydration unit natural gas flowrate or benzene emissions to meet the criteria for an exemption from control requirements under §63.764(e)(1). AIRS ID: 123/9DFD Page 5 of 18 i Health and Environment it Pollution Control Division den of flowrate of natural gas to a glycol dehydration unit shall be made using the procedures of either paragraph (b)(1)(i) or (b)(1)(ii) of this section. • §63.772(b)(1)(i) — The owner or operator shall install and operate a monitoring instrument that directly measures natural gas flowrate to the glycol dehydration unit with an accuracy of plus or minus 2 percent or better. The owner or operator shall convert annual natural gas flowrate to a daily average by dividing the annual flowrate by the number of days per year the glycol dehydration unit processed natural gas. • §63.772(b)(1)(ii) - The owner or operator shall document, to the Administrator's satisfaction, that the actual annual average natural gas flowrate to the glycol dehydration unit is less than 85 thousand standard cubic meters per day. §63.772(b)(2) - The determination of actual average benzene emissions from a glycol dehydration unit shall be made using the procedures of either paragraph (b)(2)(i) or (b)(2)(ii) of this section. Emissions shall be determined either uncontrolled, or with federally enforceable controls in place. • §63.772(b)(2)(i) — The owner or operator shall determine actual average benzene emissions using the model GRI- GLYCaIc TM , Version 3.0 or higher, and the procedures presented in the associated GRI-GLYCaIc TM Technical Reference Manual. Inputs to the model shall be representative of actual operating conditions of the glycol dehydration unit and may be determined using the procedures documented in the Gas Research Institute (GRI) report entitled "Atmospheric Rich/Lean Method for Determining Glycol Dehydrator Emissions" (GRI-95/0368.1); or • §63.772(b)(2)(ii) - The owner or operator shall determine an average mass rate of benzene emissions in kilograms per hour through direct measurement using the methods in §63.772(a)(1)(i) or (ii), or an alternative method according to §63.7()). Annual emissions in kilograms per year shall be determined by multiplying the mass rate by the number of hours the unit is operated per year. This result shall be converted to megagrams per year. • §63.774 - Recordkeeping Requirements o §63.774 (d)(1) - An owner or operator of a glycol dehydration unit that meets the exemption criteria in §63.764(e)(1)(i) or §63.764(e)(1)(ii) shall maintain the records specified in paragraph (d)(1)(i) or paragraph (d)(1)(ii) of this section, as appropriate, for that glycol dehydration unit. • §63.774 (d)(1)(i) — The actual annual average natural gas throughput (in terms of natural gas flowrate to the glycol dehydration unit per day) as determined in accordance with §63.772(b)(1), or AIRS ID: 123/9DFD Page 6 of 18 Depart ern cf P f lid Health and Environment PM fair Pollution Control Division 77 )(Hitt} ,Therc i'averag nzene emissions (in terms of benzene emissions per year) as determined in accordance with §63.772(b)(2). 17. Point 005, 006: No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) 18. Point 005, 006: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 19. Points 005, 006: This source is subject to the recordkeeping, monitoring, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 20. Points 005, 006, 007, 008: The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVII.B.2.b If a combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. XVII.B.2.d Auto -igniters: All combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto -igniter as follows: XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto -igniter upon installation of the combustion device. XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto -igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 21. Point 005, 006, 007: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve- month total must 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. AIRS ID: 123/9DFD Page 7 of 18 i Health and Environment r Pollution Control Division XVII.C.,. +I _ -m= :- _ ction .C.1.b. must be achieved within ninety (90) days of the date that the storage tank commences operation. XVII.C.1.d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks subject to Section XVII.C.1. must conduct audio, visual, olfactory ("AVO") and additional visual inspections of the storage tank and any associated equipment (e.g. separator, air pollution control equipment, or other pressure reducing equipment) at the same frequency as liquids are loaded out from the storage tank. These inspections are not required more frequently than every seven (7) days but must be conducted at least every thirty one (31) days. Monitoring is not required for storage tanks or associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. The additional visual inspections must include, at a minimum: XVII.C.1.d.(i) Visual inspection of any thief hatch, pressure relief valve, or other access point to ensure that they are closed and properly sealed; XVII.C.1.d.(ii) Visual inspection or monitoring of the air pollution control equipment to ensure that it is operating, including that the pilot light is lit on combustion devices used as air pollution control equipment; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto -igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; XVII.C.1.d.(iv) Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2., XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement AIRS ID: 123/9DFD Page 8 of 18 S tick par;=minenr of P==blidHealth and Environment Air Pollution Control Division a documented Stp .ge titfildiZmissliananagemJi(LSystem ("STEM") plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(a) A storage tank constructed on or after May 1, 2014, must comply with the requirements of Section XVII.C.2.a. by the date the storage tank commences operation. The storage tank must comply with Section XVII.C.2.b. and implement the approved instrument monitoring method inspections within ninety (90) days of the date that the storage tank commences operation. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 — Storage Tank Inspections Threshold: Storage Tank Uncontrolled Actual VOC Emissions (tpy) Approved Instrument Monitoring Method Inspection Frequency Phase -In Schedule > 6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 XVII.C.2.b.(iii) Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies) are designed to minimize emissions from AIRS ID: 123/9DFD Page 9 of 18 olor Depa en .li 'Health and Environment it Pollution Control Division ta +"4u -n iaent z: facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3.a. The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C.3.c. The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. XVII.C.3.f. A list of equipment associated with the storage tank that is designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.C.1.e., an explanation stating why the equipment is so designated, and the plan for monitoring such equipment. 22. Point 008: The separator covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. 23. Point 009: This source is located in an ozone non -attainment or attainment -maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) Point 009: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. AIRS ID: 123/9DFD Page 10 of 18 :olora= ".Depa :Health and Environment it Pollution Control Division All comment ha fees krl ttcling. ye tches). be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with the conditions (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 24. Point 009: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. OPERATING & MAINTENANCE REQUIREMENTS 25. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 26. Point 004-009: The owner or operator shall demonstrate compliance with opacity standards for all listed points, using a single EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7, Section XVII.A.II) 27. Point 008: The operator shall complete an initial site specific extended gas analysis of the gas vented from the commingled stream of the Low-pressure separator and VRT in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n -hexane, and 2,2,4- trimethylpentane content (weight fraction) of this emission stream. Results of testing shall be used to calculate site -specific emission factors for the pollutants referenced above (in units of Ib/MMSCF gas vented) using Division approved methods. Results of site -specific sampling and emissions factor analysis shall be submitted to the Division as part of the self -certification and demonstrate the emissions factors established through this initial testing are less than or equal to, the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this sampling and analysis is greater than the emissions factors established in the permit application and "Notes to Permit Holder", the operator shall submit to the Division within 60 days a request for permit modification to update emissions factors and emissions limits specified in this permit. Periodic Testing Requirements 28. Point 004: The owner or operator shall complete an extended wet gas analysis prior to the inlet of the TEG dehydrator on an annual basis. Results of the wet gas analysis shall be used to calculate emissions of criteria pollutants and hazardous air pollutants per this permit and be provided to the Division upon request. AIRS ID: 123/9DFD Page 11 of 18 Health and Environment it Pollution Control Division ADDITIONAL REQUIREMENTS 29. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC or NOx per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non -criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 30. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 31. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Reference: Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 32. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AIRS ID: 123/9DFD Page 12 of 18 ar,nen?df h s B lic°Health and Environment it Pollution Control Division AQCC Regulattso 3,.ft BSSCtion,#j,m a request for transfer of ownership and the submittal of a revised APEN and the required fee. 33. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must'be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 34. 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. 35. 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. 36. 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 cgntested 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. 37. 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. 38. 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: Christian Lesniak AIRS ID: 123/9DFD Page 13 of 18 Permit Permit Histo Issuance Date Description Issuance 1 This Issuance Issued to Bonanza Creek Energy Operating Company, LLC Health and Environment it Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.colorado.00v/cs/Satellite?c=Document C&childpaqename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&paaename=CBONWrapper 4) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # Uncontrolled ' Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 004 Benzene 71432 17540.6 Yes 849.7 n -Hexane 110543 2107.2 Yes 103.8 Toluene 108883 21054.4 Yes 972.9 Ethylbenzene 100414 7488.6 Yes 317.9 Xylenes 1330207 17410.4 Yes 719.6 224 TMP 540841 228.4 No 11.0 005 Benzene 71432 5037.6 Yes 251.9 n -Hexane 110543 32933.2 Yes 1646.7 Toluene 108883 4473 Yes 223.6 Ethylbenzene 100414 620.3 Yes 31 224 TMP 540841 3765.5 Yes 188.3 AIRS ID: 123/9DFD Page 14 of 18 Departanent ic Ptblic Health and Environment Fakir Pollution Control Division 006 Process 1 c^ ene X7142 =_ + da &0 2.4 n -Hexane 110543 308 Yes 15.4 Process 2 Benzene 71432 27 No 1.3 n -Hexane 110543 209 Yes 10.5 007 Benzene 71432 270.2 Yes 13.5 n -Hexane 110543 101.8 No 5.1 008 Benzene 71432 6629 Yes 331.5 n -Hexane 110543 43686.9 Yes 2184.3 Toluene 108883 6039.8 Yes 302 Ethylbenzene 100414 864.4 Yes 43.2 Xylenes 1330207 2535.7 Yes 126.8 009 Benzene 71432 722.4 Yes 45 n -Hexane 110543 7636.9 Yes 476.2 Toluene 108883 469.7 Yes 29.3 Xylenes 1330207 112.1 No 7 224 TMP 540841 583 Yes 36 5) The emission levels contained in this permit are based on the following emission factors: Point 004: Pollutant Emission Factors Uncontrolled lb/MMscf Throughput Source VOC 27.1724 GLYCAL 4.0 n -Hexane 0.4811 GLYCAL 4.0 Benzene 4.0047 GLYCAL 4.0 Toluene 4.807 GLYCAL 4.0 Ethylbenzene 1.7097 GLYCAL 4.0 Xylenes 3.975 GLYCAL 4.0 Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 005: Pollutant Emission Factors Uncontrolled lb/BBL Condensate Throughput Source VOC 0.5796 Promax n -Hexane 0.0189 Promax Benzene 0.0029 Promax Toluene 0.0026 Promax Ethylbenzene 0.0004 Promax 224 TMP 0.0022 Promax AIRS ID: 123/9DFD Page 15 of 18 Note: The co Point 006: Process 1 Health and Environment it Pollution Control Division control efficiency of 95%. Pollutant Emission Factors Uncontrolled lb/BBL Total Condensate Throughput Source VOC 2.16 E&P TANK n -Hexane .023 E&P TANK Process 2 Pollutant Weight Fraction of Gas (%) Emission Factors Uncontrolled lb/MMscf Blowcase Gas Throughput Source VOC 37.2 24833 Mass Balance n -Hexane 0.788 527 Mass Balance Gas throughput and emissions are based on a gas -to -oil factor of 12.08 scf/bbl, representing the volume of sales gas (process 2) emitted per barrel of slop tank liquid throughput (process 1). This factor was established by multiplying the ratio of blowcase liquids to total liquids in process 1 by the volume of sales gas released per volume of blowcase liquids released in each blowcase dump. Note: The controlled emissions for both processes of this point are based on the flare control efficiency of 95%. Point 007: Pollutant Emission Factors Uncontrolled lb/BBL Produced Water Throughput Source VOC 0.016 Promax n -Hexane 0.0001 Promax Benzene 0.0003 Promax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 008: Pollutant Weight Fraction of Gas (%) Emission Factors Uncontrolled lb/MMscf Emission Factors Controlled Ib/MMscf Source VOC 75.3 83592.2781 4179.6139 Promax Benzene 0.348 386.6837 19.3342 Promax Toluene 0.317 352.3096 17.6155 Promax Ethylbenzene 0.045 50.4238 2.5212 Promax Xylenes 0.133 147.9097 7.3955 Promax n -hexane 2.29 2548.3358 127.4168 Promax AIRS ID: 123/9DFD Page 16 of 18 Point 009: IicTHealth and Environment it Pollution Control Division n theme control efficiency of 95%. Pollutant Emission Factors Uncontrolled lb/BBL loaded Emission Factors Controlled, Lb/BBL loaded Source VOC 0.1576 0.00983 Stable oil anal. Benzene 0.0004 0.000026 Stable oil anal. n -Hexane 0.0044 0.000273 Stable oil anal. Toluene 0.0003 0.000017 Stable oil anal. 224 TMP 0.0003 0.000021 Stable oil anal. The uncontrolled VOC emission factor was calculated using AP -42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 1.0 (Submerged loading: vapor balance service) P (true vapor pressure) = 7.51 psia M (vapor molecular weight) = 33.23 lb/lb-mol T (temperature of liquid loaded) = 524 °R The uncontrolled non -criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled Emissions are based on a total control percentage of 93.77%, based on multiplying vapor collection efficiency of 98.7% by a flare control efficiency of 95%. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Requirement Status Operating Permit Synthetic Minor Source of: VOC, HAPs PSD or NANSR Synthetic Minor Source of: VOC, HAPs MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.qpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources AIRS ID: 123/9DFD Page 17 of 18 li"Health and Environment it Pollution Control Division NSPS 60.1—E— e. .. _. a:. Sn=_..'::. — KK 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 777Z — Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX 9) A self certification form and guidance on how to self -certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9DFD Page 18 of 18 Division Information Engineer: Christian Lesniak Control Engineer: Stefanie Rucker Review Date: 03/21/2016 Application Date: 09/23/2016 Facility Identifiers Permit No. 15WE1000 AIRs County# 123 (Weld Facility # 9DFD Facility Type. exploration and production facility ❑' Located in the 8 -hour non -attainment area? Potentially located in ozone nonattainment area O True Minor i Synthetic Minor for: r✓ voc (- NOx r CO Administrative Information HAPs Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: State Antelope CPF 0-1 Production Facility Source Location: SIC: SWSE Section 1, Township 5N, Range 62W 1311 Mailing Address Address 1: Address 2: ty, State Zip: Bonanza Creek Energy Operating Company, LLC 410 17th St., Suite 1400 Denver, CO 80202 Person To Contact Name: Phone: Fax: Email: Jerry Dismukes 303-803-1724 720-305-0802 Jismukes@bonanzacrk.com Requested Action Self Certification Required? Issuance Number: Yes Source Description: Oil and gas exp oration and production facility known as the State Antelope CPF 0-1 Production Facility, located in the SWSE Section 1, Township 5N, Range 62W, Weld County, Colorado. Point Name Type Control Action 004 DEHY-01 Dehydrator Flare Newly reported source 005 CNDTK-01 Condensate Tanks Flare Newly reported source 006 SLOP -01 Condensate Tanks Flare Newly reported source 007 PWT-01 Water Tanks Flare Newly reported source 008 LPGFL Separator Venting Flare Newly reported source 009 L-01 Loadout Flare Newly reported source One (1) natural gas dehydration system using methylene glycol (Make, Model, Serial Number To Be Determined), design rated at 12 mmscf per day, consisting of: one (1) natural gas fired glycol regenerator boiler, rated at 0.50 MMBtu/hr; Two (2) gas -driven Kimray 21015 PV glycol recirculation pumps with a glycol redrculation rate of 3.5 (gal/min). Only one Kimray gas -glycol pump will be operated at any given time. The second Kimray gas -glycol pump serves as a back-up only. This unit is equipped with a flash tank, 004 reboiler and still vent. Stripping gas is not used. Emissions from the still vent are routed to an air-cooled condenser and then to a flare with a minimum control efficiency of 95%. Emissions from the flash tank are 100% recycled to the sales gas line or to the fuel gas system. Requsted Throughput 4380 MMscf/year Glycal Emissions tons/year VOC Benzene n -Hexane Toluene Ethylbenz Xylene 224 TMP Recycled (No emissions) Flash Tank 110.4103 0.6747 2.0854 0.5605 0.1246 0.2026 0.2336 Uncontrolled Regenerator After condenser 59.5076 5442 8.7703 1.0536 10.5272 3.7443 8.7052 0.1142 8.4972 1.0375 9.7289 3.1787 7.1956 0.1101 Controlled Combined 2.721 0.42486 0.051875 0.486445 0.158935 0.35978 0.005505 Control Efficiency Flare 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 27.17 lb/MMscf 59.5 tpy 2.7 tpy GLYCAL 4.0 Benzene 4.00lb/MMscf 17540.6 lb/yr 849.7 lb/yr GLYCAL 4.0 n -Hexane 0.481 lb/MMscf 2107.2 lb/yr 103.8 lb/yr GLYCAL4.0 Toluene Ethylbenze Xylene 224 TMP 4.807 lb/MMscf 21054.4 lb/yr 972.9 lb/yr GLYCAL4.0 1 710 lb/MMscf 7488.6 lb/yr 317.9 lb/yr GLYCAL 4.0 3.975 lb/MMscf 17410.4 lb/yr 719.6 lb/yr GLYCAL 4.0 0.052 lb/MMscf 228.4 lb/yr 11.0 lb/yr GLYCAL 4.0 Control Percentage 95.43 95.16 95.08 95.38 95.76 95.87 95.18 16994.4 2076.12 19447.2 6359.76 14366.4 219.876 Condenser SIT lb/hr 1.94 0.237 2.22 0.726 1.64 0.0251 Secondary Emissions Fuel Heating Value (btu/scf) Gas throughput to combustor (scf/yr) Combustion energy (MMBTU/yr) 1723 1419120 2445.14376 From Glycatc (Condenser Vent Stream) 162 scf/hr Nox co 0 068 0310 Ib/MMBTU Ib/MMBTU 0.08 0.38 tpy tpy 0.08 0.38 tpy tpy AP -42 AP -42 Regulatory Review Section 11.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60. Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A,5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is In excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 — Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 8 - NESHAP MACT HH - Source is an area source of HAPs, and meets MACTT HH Benzene Exemption (Actual Benzene emissions are below 1 ton per year). Facility is not major for HAPs Regulation 7 — Volatile Organic Compounds XVII.B S D STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS. Applicant is subject to XVII.B.2 - Combustor will emit no visible emissions, be enclosed, be equipped with auto -igniter by May 1, 2016. Applicant is subject to XVILD - Still vent emissions shall be controlled Notes - Flash gas emissions are recycled to sales line, or in event this is not possible, used for fuel for engines. Source says that flash gas pressure is higher than sales line, so downtime is not expected. Therefore, I am not going to account for flash gas in the PTE, although flash gas emissions are noted above. 005 Ten (10) above ground 500 bbl atmospheric condensate storage tanks. Tanks are controlled by enclosed combustor(s) with 95% control efficiency. Requsted Throughput 1742495 bbl Control Flare Efficiency 95.00%! Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.5796 lb/bbl 505.0 tpy 25.25 tpy Promax Benzene 0.002891 lb/bbl 5037.55305 lb/yr 251.8777 lb/yr Promax n -Hexane 0.0189 lb/bbl 32933.1555 lb/yr 1646.658 lb/yr Promax Toluene 0.002567 lb/bbl 4472.98467 lb/yr 223.6492 lb/yr Promax Ethylbenze 0.000356 lb/bbl 620.32822 lb/yr 31.01641 lb/yr Promax 224 TMP 0.002161 lb/bbl 3765.5317 lb/yr 188.2766 lb/yr Promax Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 — Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 10,000 bbl before custody transfer. NSPS 0000: for storage vessels in the natural gas production, transmission, and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Regulation 7 — Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks since it is located in a non -attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 6 tpy of VOC.) 006 one (1 I soave ground 800 Dol slop tank ror storage or compressor conoensate Dropout and sales oil reject. Additionally, sales gas is used to push compressor dropout into the slop tank and emitted in the process. Tank is controlled by enclosed combustor(s) with 95% control efficiency. Process 1 ids from Blowcase Compressor Dropout Liq Actual Throughput 234 bbl Requsted Throughput 278 bbl Sales Oil Reject Actual Throughput 10950 bbl Requsted Throughput 13031 bbl Combined blowcase liquids and sales of reject Actual Throughput 11184 bbl Requsted Throughput 13309 hhl Process 2 Blowcase Sales Gas Emissions Actual Throughput Requsted Throughput 132.3 mscf mscf 397 Control Efficiency Flare 95.0094 Gas to liquids conversion factor 0.02137 Liquid ratio (Designed blowcase liquid/Total liquid) scf/bbl for blowcase gas to blowcase liquids scf/bbl for blowcase gas to total liquids 565.3846 12.08219 Based on design rate of 15scf/hr Requested 3x buffer Emissions Summary Table - Compressor Dropout Liquids from Blowcase (See Combined table for final emissions) Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 76.28 lb/bbl 10.6 tpy 0.5 tpy E&P TANK Benzene 0.029 lb/bbl 8.062 lb/yr 0.4031 lb/yr E&P TANK n -Hexane 0.218 lb/bbl 60.604 lb/yr 3.0302lb/yr E&P TANK Emissions Summary Table - Sales Oil Reject (See Combined table for final emissions for process 1) Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.58 lb/bbl 3.8 tpy 0.2 tpy Promax Benzene 0.003 lb/bbl 39.1 lb/yr 1.95465 lb/yr Promax n -Hexane 0.019 lb/bbl 247.6lb/yr 12.37945 lb/yr Promax Emissions Summary Table - Process 1- Combined blowcase liquids and sales oil reject Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 2.16385193 lb/bbl 14.4 tpy 0.7 tpy E&P TANK Benzene 0.00354399 lb/bbl 47.2 lb/yr 2.358349 lb/yr E&P TANK n -Hexane 0.02316363 lb/bbl 308.3 lb/yr 15.41424 lb/yr E$P TANK Throughpu MW 0.397 25 3274 MMscf/yr Ib/Ib-mol 45.3196347 0.00108767 scf/hr MMscf/d Flowback Sales Gas Analysis - State Antelope J-1 Sample 1 Sample 2 25.6576 24.9972 MW mole 5/0 MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.39 44.01 1.052 0.042 0.13 1101.54 0.55 N2 0.56 28.013 0.157 0.006 0.02 164.40 0.08 methane 64.94 16.041 10.417 0.411 1.25 10912.02 5.46 ethane 14.27 30.063 4.290 0.169 0.51 4493.56 2.25 propane 10 46 44.092 4.613 0.182 0.55 4831.66 2.42 isobutane 1.15 58.118 0.669 0.026 0.08 700.68 0.35 n -butane 3.62 58.118 2.105 0.083 0.25 2205.16 1.10 isopentane 0 70 72.114 0.508 0.020 0.06 531.68 0 27 n -pentane 0.91 72.114 0.657 0.026 0.08 688.39 0.34 cyclopenta 0.10 70.13 0.069 0.003 0.01 71.81 0.04 n -Hexane 0.23 86.18 0.200 0.00788 0.02 209.03 0.10 cyclohexan 0.08 84.16 0.070 0.003 0.01 72.99 0.04 Other hexa 0.30 86.18 0.259 0.010 0.03 271.36 0.14 heptanes 0.07 100.21 0.066 0.003 0.01 69.23 0.03 methylcycic 0.06 98.19 0.058 0.002 0.01 60.68 0.03 224-TMP 0 02 114.23 0.027 0.00108 0.00 28.60 0.01 Benzene 0.03 78.12 0.025 0.00100 0.00 26.59 0.01 Toluene 0O3 92.15 0.026 0.00103 0.00 27.27 0.01 Ethylbenze 0.01 106.17 0.007 0.00029 0.00 7.73 0.00 Xylenes 0O1 106.17 0.013 0.00052 0.00 13.90 0.01 C8+ Heavi 0.03 151 89008 0.040 0.00158 0.00 42.00 0.02 VOC mass ft 0.372 Total VOC (Uncontrolled) 4.93 Emissions Summary Table - Process 2 - Blowcase Sales Gas Emissions Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 24833.1648 lb/MMscf 4.9 tpy 0.2 tpy Mass Balance Benzene 66 9894459 lb/MMscf 26.6 lb/yr 1.329741 lb/yr Mass Balance n -Hexane 526 516596 Ib/MMscf 209.0 lb/yr 10.45135 lb/yr Mass Balance 0 2.4691 0.5177 63 7916 14 6972 10.8559 1.2007 3.7643 0 7304 0.9405 0.1006 0.238 0.0987 0.3094 0.0683 0.0614 0.0245 0 0332 00291 0.0071 0.0129 0.0274 0 2.3098 0 6028 66.0914 13.8417 10.0667 1 1012 3 4802 0 6773 0.8821 0.0949 0.2251 0.0669 02918 0.0636 0 0566 0 0233 00318 0.0274 0.0068 0.0121 0.0254 Notes Source has explained that slop tank has three different emission sources. One is compressor knockout liquids which come from blowcase. Emissions for these liquids were estimated very conservatively and throughput is small. Another source of emissions is rejected sales oil which is rerouted back into this tank. Even though this liquid has already flashed, emissions are estimated conservatively by using the emissions predicted for pre -flash condensate. This liquid makes up the majority of the liquid throughput in the tank. I have combined these two liquid sources into a single process with a single emission factor, based on the predicted ratio of the two liquids, averaging the emission factors according to this ratio, and assuming that this ratio will be stable oer the life of the tank. Because the calculations for both streams are rather conservative, and because overall, this tank is not a large VOC emitter, I am comfortable making these assumptions. The additional reason that these two streams have been combined is that the method of measuring the throughput by tank levels measures the total liquid. The third emission source is the gas used to push the compressor dropout liquids from the blowcase into the tank. This gas is sales gas. The blowcase dumps when the liquid level reaches a certain volume, and each dump is assumed to require the same volume of gas. Therefore, a link between the gas throughput and the liquid throughput can be established in terms of scf sales gas / bbl oil throughput. The sales gas throughput and emission factor is a separate process and expressed in terms of act rather than the bbl used for the liquid throughput. Although the gas throughput cannot be directly measured, it can be correlated to the liquid throughput. I believe this to be a reasonable assumption based on a given volume of gas being used for each liquid dump, which is a constant volume. Although requested values are higher than design rates for all emission sources, the factor connecting the gas throughput to the liquid throughput has been established by using design rates, to establish the fixed connection between sales gas emitted and liquids into the tank from a single blowcase dump, and keeping in mind the ratio of blowcase liquids to the total liquids in the tank, which is the measured parameter for establishing throughput. Sales gas speciation is the average of two samples at Antelopel-21, sampled on 7/14/2015 Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 — Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits'. For areas used predominantly for residential or commercial purposes d is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air, Regulation 6 - New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because each tank is less than 10,000 bbl before custody transfer. NSPS OOOO: for storage vessels in the natural gas production, transmission, and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Regulation 7— Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks since it is located in a non -attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 6 tpy of VOC.) 007 Three (3) above ground 500 bbl produced water storage tanks. Tanks are controlled by enclosed combustor(s) with 95% control efficiency. Emissions Calculations Requsted Throughput 1121280 bbl Control Efficiency Flare 95.001 Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.016 lb/bbl 8.97024 tpy 0.448512 tpy Promax Benzene 0.000241 lb/bbl 270.22848 lb/yr 13.511424 lb/yr Promax n -Hexane 0.0000908 lb/bbl 101.812224 lb/yr 5.0906112 lb/yr Promax From Sample taken 4/11/2016 Gastowater ratio below .5 scf/bbl -> assume 0.5 scf/bbl 280612554 VOC volume percentage 14.948 Average molecular weighs 33.4842 Emission Calculation Method Throughput 0.56064 MMscf/yr 64 scf/hr MW 33.4842 Ib/Ib-mol 0.001536 MMscf/d mole % MW lbx/lbmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 31.2757 44.01 13.764 0.411 2.32 20361.20 10.18 N2 4.3852 28.013 1.228 0.037 0.21 1817.16 0.91 methane 29.1420 16.041 4.675 0.140 0.79 6915.06 3.46 ethane 20.2491 30.063 6.087 0.182 1.03 9004.98 4.50 propane 9.9486 44.092 4.387 0.131 0.74 6488.83 3.24 isobutane 1.0838 58.118 0.630 0.019 0.11 931.76 0.47 n -butane 2.1547 58.118 1.252 0.037 0.21 1852.43 0.93 isopentane 0.2754 72.114 0.199 0.006 0.03 293.78 0.15 n -pentane 0.3397 72.114 0.245 0.007 0.04 362.38 0.18 cyclopentan 0.2197 70.13 0.154 0.005 0.03 227.92 0.11 n -Hexane 0.3191 86.18 0.275 0.008 0.05 406.80 0.20 cyclohexane 0.0186 84.16 0.016 0.000 0.00 23.16 0.01 Other hexar 0.3480 86.18 0.300 0.009 0.05 443.64 0.22 heptanes 0.0078 100.21 0.008 0.000 0.00 11.56 0.01 methylcyclo 0.0203 98.19 0.020 0.001 0.00 29.49 0.01 224-TMP 0.0000 114.23 0.000 0.000 0.00 0.00 0.00 Benzene 0.0000 78.12 0.000 0.000 0.00 0.00 0.00 Toluene 0.0000 92.15 0.000 0.000 0.00 0.00 0.00 Ethylbenzer 0.0014 106.17 0.001 0.000 0.00 2.20 0.00 Xylenes 0.0000 106.17 0.000 0.000 0.00 0.00 0.00 C8+ Heavie 0.2109 115.244365 0.243 0.007 0.04 359.53 0.18 VOC mass fr; 0.231 otal VOC (Uncontrolled) 5.72 Sampled Emission factor 0.01019681 lb/bbl Notes - Promax was used to determine produced water tank emissions. Inputs to model are from a weighted average of sales gas flowback inputs, not from an actual analysis of pressurized produced water. Source then provided sampled flash liberation analysis, giving a very low gas -to -water ratio, and used a more conservative value of 0.5 scf/bbl to calculate emissions. The sampled speciation and emissions are given above, and emission factor is much lower than the modeled promax run. The operator has asked to use the promax run as a more conservative estimate of emissions, and I am okay with that. I will therefore not require any further sampling for this point. Regulatory Review Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15 -second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 - Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2 —Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 7 —Volatile Organic Compounds XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 6 tpy of VOC.) One low-pressure separator controlled by one enclosed flare curing VRU downtime- Flare has a minimum 008 control efficiency of 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are. recompressed Natural gas venting from a well head separator. Emissions from this source are recompressed. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication Volume II, Chapter 10 - Displacement Equation (10 4-3) Ex =Q' MW Xx / C Ex = emissions of pollutant x Q = Volumetric flow rate/volume of gas processed MW = Molecular weight of gas = SG of gas MW of air Xx = mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Throughput (O)1 MW 1714332 42.1 MMscf/yr Ib/Ib-mot 1957 0.046968 scf/hr MMscf/d H2S 0.000015 mole % MW Ibx/Ibmol mass fraction lb/hr lb/yr tpy Helium 0.00 4.0026 0000 0.000 0.00 0.00 0.00 C02 2.2335 44.01 0.983 0.023 5.08 44462.41 22.23 N2 00914 28013 0.026 0.001 0.13 1158.14 0.58 methane 224780 16041 3.606 0.086 18.62 163096.57 81.55 ethane 19.3070 30063 5.804 0.138 2997 262544.45 131.27 propane 27.8722 44.092 12.289 0.292 63.46 555887.32 277.94 isobutane 3.8374 58.118 2.230 0.053 11.52 100879.62 50.44 n -butane 12.6653 58.118 7.361 0175 38.01 332952.18 16648 isopentane 2.4129 72.114 1.740 0.041 898 78707.23 39.35 n -pentane 2.9801 72.114 2.149 0.051 11.10 97208.93 48.60 cyclopentane 0.5248 70.13 0.368 0.009 1.90 16647.67 8.32 n -Hexane 1.1207 86.18 0 966 0.0229 4.99 43686 94 21.84 cyclohexane 0.3781 84.16 0.318 0.008 1.64 14393.56 7.20 Other hexanes 1.9613 86.18 1.690 0.040 873 7645506 38.23 heptanes 0.7081 100.21 0.710 0.017 3.66 32096.77 16.05 methylcyclohexane 0.3130 98.19 0.307 0.007 1.59 13901.68 6.95 224-TMP 0.0944 114.23 0.108 0.00256 0.56 4877.62 2.44 Benzene 0.1875 78.12 0.147 000348 076 6626.04 3.31 Toluene 0.1449 92.15 0.134 0.00317 0.69 6039.76 3.02 Ethylbenzene 0.0180 106.17 0.019 0.00045 0.10 864.43 0.43 Xylenes 00528 106.17 0.056 0.00133 0.29 253566 1.27 C8+ Heavies 06185 176 1673869 1.090 0.026 5.63 49285.70 24.64 VOC mass frac 0.753 Total VOC (Uncontrolled) 71652 Notes Mole %. MW. and mass fractions from weighted promax output between Ip separator and VRT. LP separator gas is responsible for 66% of throughput with VRT responsible for 34% of throughput. Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+ based on the average MW given for total gas. Source I will require initial gas sample of both Ip separator and VRT gas emissions streams. to be combined to determine compliance with the emisison limit for this point. Because the separate streams are not metered, the operator should use the the same throughput weighting as above to determine the weight average. using the gas compositions as determined by initial testing. 15WE1000.CP 1.xlsm One low-pressure separator controlled by one enclosed flare during VRU downtime. Flare has a minimum 008 control efficiency of 95%. Flaring Information Equipment Description Enclosed Flares to combust low-pressure separator as durino VRU downtime. Manufacturer Unknown Model Unknown Serial Number 80014.80016.80053-80058 Gas Heating Value 2339 Btu/scf Throughput 40098.22548 MMBtu/yr VRU Information Equipment Description Engine to recompress as to sales line. Make TBD Model TBD Requested Control 0.00 % Annual Bypass Tim 100.00% Backup Flare Overall Control 95.00% Combustion emission factor source: 0.068 Ilb NOX/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 83592 lb/MMscf 4179.61 lb/MMscf 716.5 tpy 35.8 tpy Promax Nox 0.068 Ib/MMBTU 0.068 lb/MMBTU 1.4 tpy 1.4 tpy AP -42 CO 0.31 Ib/MMBTU 0.31 Ib/MMBTU 6.2 tpy 6.2 tpy AP -42 Benzene 386.68 lb/MMscf 19.33 lb/MMscf 6629 lb/yr 331 lb/yr Promax n -Hexane 2548.34 lb/MMscf 127.4168 lb/MMscf 43687 lb/yr 2184 lb/yr Promax Toluene 352.310 lb/MMscf 17.6155 lb/MMscf 6040 lb/yr 302 lb/yr Promax Xylenes 147.910 Ib/MMsd 7.3955 lb/MMscf 2536 lb/yr 127 lb/yr Promax Ethylbenzene 50.424 lb/MMscf 2.5212 lb/MMscf 864 lb/yr 43 lb/yr Promax AP -42: Chapter 13.5 0.31 IIb CO/MMBtu Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity.' AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed, hydraulically fractured, or recompleted on or after August 1, 2014? yes This separator is subject to Reg 7, Section XVII.G. and control requirements of Reg 7, Section XVII.B.2 15WE1000.CP1.xlsm 009 Hydrocarbon Loadout to Tanker Trucks Calculations L= 12.46*S*P*M/T (AP -42: Chapter 5.2, Equation 1) L = loading losses in lb per 1000 gallons loaded The table of inputs below enables you to calculate the loading loss emissions factor "L". If you choose to use a state default emissions factor, you may enter is directly into cell 814 in units lb/1,000 gallons which will overwrite Factor Meaning Value Units Source S Saturation Factor 1 AP -42 P True Vapor Pressure 7.51 psia Sales oil co M Molecular Weight of Vaf 33.23 lb/lb-mole Sales oil co T Liquid Temperature 524 deg. R Field Data VOC weight fraction according to speciation 0.6324 L 3.753 lb/10^3 gal 1.58E-01 lb/bbl Annual requested Throughput Annual requested VOC emissions Control: Flare Efficiency: 93.77% NCRPs Component Benzene 0.0026 n -hexane 0.0278 Toluene 0.0017 Xylenes 0.0004 224 TMP 0.0021 Source: Mass Fraction Stable Sales Oil Analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.1576 lb/bbl 137.3 tpy 8.6 tpy Stable oil anal. Benzene 0.0004 lb/bbl 722.4 lb/yr 45.0 lb/yr Stable oil anal. n -Hexane 0.0044 lb/bbl 7637 lb/yr 476 lb/yr Stable oil anal. Toluene 0.0003 lb/bbl 470 lb/yr 29 lb/yr Stable oil anal. Xylenes 0.0001 lb/bbl 112 lb/yr 7 lb/yr Stable oil anal. 224 TMP 0.0003 lb/bbl 583 lb/yr 361b/yr Stable oil anal. 1742776 BBL/yr 73196592 gal/yr 274688 lb/yr 137.34 tpy mposition analysis mposition analysis Based on flare efficiency of 95% and vapor collection efficiency of 98.7% Controlled Emission Factors Pollutant Emission Factor VOC 0.00983 lb/bbl Benzene 0.000026 lb/bbl n -Hexane 0.000273 lb/bbl Toluene 0.000017 lb/bbl Xylenes 0.000004 lb/bbl 224 TMP 0.000021 lb/bbl Regulatory Review Regulation 3 - APEN and Permitting Requirements Is this site considered an exploration and production location (e.g. well pad)? If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons 123t BBLsl per day of crude oil on an annual average basis? If yes, this emissions point is categorically exempt from permit requirements per Regulation 3, Part B Section 11.0.1.'. Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? If yesthis emissions point is categorically exempt Rom permit requirements per Reguiatton 3. Part B. Section 11. D.1.1 No Yes No 7n 0 M N T .172 U _ L lc o O f C 0 c cad _ • 0. tai F < C o c w o u LI a. 2 S ,r Section 02 — Re Section 01 — Administrative Information V R L 0 o▪ c 0 0 V o< .V. C I. C C[ C U C 0c C P r ❑ ❑ 0 ® ❑ ❑ ❑ 9.1 J R. 0 0 Y N 04 ti r V d C Q — O 7 U V V U r01 v z R�3 V 0 z C) 0 U. 1. N C - N 410 171h Street, Suite 1400 Mailing Address 0 C r. O N M = r1 Phone Number: Person To Contac C) 0 Section 03 — General Informatio❑ UI 0 N 2.1 t 0 Y 0 J v 0 J C 0 ) C) 0 U O c 0 L 0 Y T ^O N >, 0 N 0 c In ❑ ❑ ❑ z z z ❑ ❑ C) v r >- >- ® ® ❑ 0 0 Z 0 u 0-- o N < m ti 0 c v j G W ; D a F. 1 _ s 0 • 'J T > V 3 • r. E 5 • T p > o 70 > (- o v � 0 0 G G C E V 7.a F- ex) a a c �m z. O O z yd. L p U d = U 0 C 0 U < a ci V O F v" V ^ L n eCC eC- C N N N1.1 P5 R 0 o C _ a z _ W < U. en V V G C) V 0 2 ic G uinment Information dration Unit E Section 04 — Deh z en y v7 C C 0 S o W Ti 3 L [0 u u h N j N 0. G co 7 V W en n' 00 to ri U S gft O C ti Ur ❑ W 2 m 1 P N J 0 c tel N C) U a J tv C h J F ❑ a 22 z 0 F 0 N r V 0 0 v F .5 G n o c. `n y � J T ▪ i7 0a c ▪ 0 ✓ 0 • 0 O 0 X x L .C L 0 0 O 0 C ore, El 0 U •0 x C) co;XI 1. < r � 0 .= F— c 0 >• 7r. . O „ J } 7 n C V co (33 tE G " L .0 n co c J .. 0 R d ._ • 0 0 1. CD CY) Ct) FORM APCD-202 Permit Number: Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) C) -0 0) • 0 E O U_ C 0 CO E C rti CO R C 0 ✓ d N N CO M N CO N N N 7 O U _ CO F-' w u 2 o gel r; C) W N 0 ❑ Other (Describe): Width (inches) _ O Horizontal ❑ Down ❑ Other: Length (inches) = C CO 00 ti m 0 CO . Circular: Inner Diameter (inches) = C 0 0, E C) 0 CO C 00 0 C CC C C 0, C N Y O 0 O U G) :> C) s in i0. U CID Section 08 — Emissions Inventory Information & Emission Control Information 0 a 0 C O CS .0 G O r w 0 u L CO O E L C CO C C C. C C w C C 0 O E CO Cat,' .°.. w C 0 E Estimation Method or Emission Factor Source AP -42 GRI-GlyCalc 4.0 N 1' GRI-GlyCalc 4.0 GRI-GlyCalc 4.0 GRI-GlyCalc 4.0 GRI-GlyCalc 4.0 II GRI-GlyCalc 4.0 Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions' Controlled (Tons/Year) 0.07 2.72 0.32 0.42 0.49 O 0.36 0.05 Uncontrolled (Tons/Year) cri 8.77 M O 3.74 00 ,,.i Actual Calendar Year Emissions2 Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor .0 lb/MMscf CO`0 V rn lb/MMscf W V co w u En W u rA g Uncontrolled Basis CA O O 27.17 CZ M O O 7 CA 7 1.71 3.97 er O Control Efficiency (% Reduction) Identify in Section 07 Please use the APCD Control Device Description Secondary 8 P. Pollutant xO11 VOC II CO Benzene Toluene Ethylbenzene Xylene n -Hexane 0 VO▪ 4 L GD 11.1 g T1 ca C • C 7E• 6 L L CO w C'' d O u 0 O CO U CO S .L' d CO C 0 CO E L CO C C CO C) s CO d C 0 O u O E a w w7a L C) u C L C) 0 0 CO u m 1 U ' Section 09 —A CO CO 0. 0. C0 'O 0 7 00 C) 0 G) a I- 0 00 in 3 Form APCD-202 Glycol Dehydrato N 0 N C) 00 O h F A d cep CC C 0 C O E U Q E 00 C) Co U z U Rested Action (Check applicable request b Section 02 — Re Section 01— Administrative Information g • W W � U v — z z 3 ` d i04 o z W F a v C C z x` `0 0- o U U < z 0') 0 0 .0 Y CV) C) 4 oo a. C7 > ❑ y 0 z O U 0 O w � O ❑ z 3 Change company name N 00 00 a - 0 U U u N Source Location! 410 17th Street, Suite 1400 P 0 `oo L S h W 0 m J V V < 0 3 c W Y 0 c 0 C c F W m u 9 .00 a W a E t E J y ❑ ✓ y O ti e o .V. O 8L 'y o L o F F 720-305-0802 onanzacrk.com Y E G E-mail Address: tn N 0 C 0 0 U0. 0. G E a c s. m Y T a C C C CG C low ov V^i '- C = C C m2 a 0 Ai =0 0.5 m C C E .3 o C L• a .� r J.F ❑ 00 d �L N o 0 a eCj J p - T L U TT: c R L c sew' m e m m e o — 0 O E AI 0 v o L N O L W C ^ W 2 < p a < c o z O > V. vJ 9 En E J W ail o o E w e 0 >. o= oo w E C L W U c O a W W C• e g o.o 0 Ey W?. 'OUoo 0 L ° J C) C e 3 c h 9 �� w C+' C 00050c N 0 c c F• v 0c L v 5 o C 0 W 05 > a 0 P. aCi Ua'°? g CU<QG ea > c c P. E c d p c 61 61. a T p C C L V J W Z` V e v `p .p. a s 00 E i .V 0 V C) .N.. W E_ J c art u C W c . CD ). C ,J a� a Duo. W w° x J 0 N W F o m , .. ( .'I o. ea p m — E0. rv» i G A U= a 0 c' t C) :` m y n..' -'� K u S 9 8 W 37 act Woo a aCi C) t Wi t, o L o a c 0= c L C u s 3 as = 1 y O'^ `0 C.0 -re'en r- M N N 0 a M V € c CU a P. < < .O r L T co O a Actual While Controls Operational: e N c a GO b a e N External Floating Roof F C C < _ rIVI a N 0 0 S . 0. F 0 -F Ft, y 0 • ax 0 00 m 9 m n ca ru y C 1 O L F v N 0 N 0 C s C, F m o E `o co V o 0- o y II! t c C �+ Ut 0 N 0 o E v c W y C C J C .' V W o. E.3 t O O uj L L e e U c Wells Serviced by this Storage 'rank or Tank Battery (E&P Sites Only) I Newly Reported Well I El ■ S ■ ■ Name of Well See Attached Addendum API Number z z ECE F dI Fonn APCD-205-Condens O V 00 0-, FORM APrn_zn5 ao 0 v t ree O en N e N O O z For Midstream sites onl Section 05 — Stack Information o1 a a Cu o< a -•• Ea c d s b 0O �C Uo Z an u s g C o o s .0 2 C at Requested VOC & HAP Control Efficienc a? Annual time that VRU is bypassed ( Y 00 0 0 E&P Sites On Information aration Technolo Zn Section 08 — Gas/Li C Flow Description and Diagram. See Attached Proce O 0 at E L L G U C 0 E 0 O E C 0 O C i c Emission Factor Data Source e N 0. < Promax Model H N co. 4 Promax Model Promax Model Promax Model Promax Model Promax Model Promax Model Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) rel. O a 25.25 3.74 'D N a N r a � 0 a V1 e O a N1 N CO O C 01 O W. Uncontrolled (Tons/Year) I VN L a e h NA P en N b 'n N N O -, ery O Vl O P O ' `o ". •.-4 K 00 00 Actual Calendar Year Emission Controlled (Tons/Year) O O e O• N ri in .- a o,, 0 a en 0 a 00 0' a ,c a 00 0 e Uncontrolled (Tons/Year) I VN a VN O oa N N . till Emission Factor Units a L rt a E Z t Z Z. Uncontrolled Basis oa w 0•• a oo O ^ O en ce 0 a en O 0 a e ° 0 O• 0, o O 0, H t a N e2 0 O A J o 0 z DOA — J y m= y o Ethylbenzene C a x K N y c A C a1 L 1 •5 v N ea m v II i u'I N 03 1 c 6 0 E 0 0 L V 0 Q W ea m a. g 4 1 E a U 9 d Y o E ;, E �?g a a mv c 1 c C N 9 E 0 CO O m t_-i U E C D ¢ w Tom-' o m 3 eo at o v C 1. w m g r. m C O O G 0 e 1 .o 'v ae E .E .v s yz, E, 9 o. v r C x v m O c V O A O or L , W .. ._ E C ......•_ W . V 0 m 0 F C ❑ - ti w t se = o ,,, c l„a' et 02 Y ro Q O y ..Q v," 1 \ 0 a- E 6� 1 L 1 O z co 9 a: 0 1. N < o Er ° et mo F. L et C } J a" et n V A O U y � ao E O- — Cs O F... itl .1 O C 0 r c m_ „ in El Section 10 —A EE❑ z z ❑ L 0 FORM APUD-2115 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: State Antelope CPF O-1 (COGCC# 440823) Emissions Source MRS ID2: 123 / / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41151 State Antelope 24-1-36XRLNB I 05 - 123 - 41147 State Antelope J-1-36XRLNB VA 05 - 123 - 41148 State Antelope J14-1-36CRLNC 0 05 - 123 - 41149 State Antelope J24-1-36XRLNC VA 05 - 123 - 41150 State Antelope O24-1-36XRLNC I 05 - 123 - 41154 State Antelope T-1-36XRLNB VA 05 -123 - 41155 State Antelope Y-1-36XRLNB VA 05 - 123 - 41159 State Antelope 44-1-36XRLNB VA - - ❑ - - ❑ ■ ■ - ❑ - ❑ Footnotes: Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 dl a Form APCD-212-EP-StorageTank-APEN-Addend um_Condensate.docx Emission Source AIRS ID: [Leave blank unless APCD has already assigned a permit N & AIRS ID] [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] C O stp Ca 0 a.� = Z w ia 0. cal P. w uested Action (Check applicable request boxes) Section 02 — Re Section 01 — Administrative Information 3 s Ca ° p a _ C 0 a IDC O a O O L Y V 0 L 0 0. 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O' C Q, 6 ai 0 a �' 00 et Foe a ° -o o cog. o .o ro ro Cp c e° 0 N N 0 Y V Ft- • • U C U m v H -E. � Y V ° V y L a E ` „. o Ca 0 O °r e O h o 0 n Lo C O U) 0 0 to N 0 0 N 9 O E Cv Ca C C 7 Z3 9 7 a a oc O elp O It C O CO Wells Serviced by this Storage Tank or Tank Battery (E&P Sites Only) Newly Reported Well ❑ ❑ ■ ■ ■ Name of Well API Number to-Tanks-APEN Slop di Fonn APCD-21)5-fond 001 c 00 CC FORM APell-205 M N Emission Source MRS ID: Permit Number: X L 00 r b E ❑ O 0 0 O 0 0 0 0 .O 0 v O U wes 0 U V] O a _ o 0 P. o C a d e �vra 0 5 00 U R 00 O V .2 Uj O t O V �s U co O .C u 0 0 0 1- J E O a -104.27127 ti en G z U 0 0 LW a b a o z o° 6 u 0. 0 c 00 00 c 0 II C V c 3 `0.. R V c m aa > O c cc U 7.7 .. v O N .Z N v - A 0 t o at 00 o 2 bb J c ea esc z L) =et oan Y � F m .a a O r .O G ce used for control o Combustion De Enclosed Flares T F 00 Manufacturer Guaranteed: c_.8 65 m .2 W C � O 0 a z P 0 n U o e EID 0) 0 v > 7 J 0 N a 2 J - 7 Lc u O c U >, ¢cc O > N J - ¢ Information O .O ass q O R a cep en et DD 0 e O at —J J E R C ecs 0 G 0. L U a a 0 y o y - 0 o C- a D v r p c O a O d o c4 W c 0 0 0 o ro 0o g O at 0 O ? C G ^ O 0 5 > O L O .O - m u, i Cl 'OD) y m '7 O C0. 77 O O 0 'a .. t a O y O v y C m U p W C o 0 d a r7 0 o° roP. v. o o o' g -go W AP42 Tbl 13.5-1 F N ¢ 0 F 6. K C 2 Promax Mode Promax Mode F C itted Emissions C V N C a v U - O naga Controlled (Tons/Ye 9 O O C O C c 0' C CO C \. .0 T C q 9 O O O. S C C z U C C U Y N C F V N au Y N 0 a. U F N listed above. 0 ea. O d d 0 E E 0 Q C C 0 Q a a 0 W P. R O R Co, L .9 R U Li /so U _R 0 C a v E e 0 0 00 W F W a O, R s a 0 herein and information sub Q U u CO w c N G O q ¢ O - Tz F T. 0 4 ,w 9 Z a •O '4 g N ¢"o 0 0 0. C C Q. I- 0 0 I) C v 0 O Y U c 0 C 0 0 a U C 9 O 6 O C or Y U 0 E C C C W C E O•E . a 0 ¢ C N N 0 00 ?. FORM APUTL21IS Emission Source AIRS ID: ready assigned a permit # & AIRS ID] Section 02 — R Section 01 — Administrative Information 7 0 0 C z a" ❑ ti O U_ U v z� a a E 0 eo 0. bt L O `a C " " L U c C U C 0 O T a v h Tee 0 c '0 a 6 a 4 N U 0 o 0 '' 1. V c U " V (7)o Source Name: Change company name a) Transfer of ownership ❑ ❑ Change process or equipment Change permit limit C ❑ ❑ a 3 c U x z F G z W rin rip Source Location: w N O 00 U C G U 410 17th Street, Suite 1400 O U C APEN Submittal for update only (Please note blank APEN's will not be accepted) Jerry Dismukes Person To Contac Section 03 — General Information 0 000 a T Z z 7,7Z ❑®®®❑ Tv " a 3 N 0 0 0 U >- r_ Itopoo® A 0. 0 U S U d a f, • „ .0 0 a at a • c `c . •o '0 ° E U • L 2 w ti N e N 0 ❑ 'm a -Lv U F F- ' p"p p E U 0 • t:.. " C a c e U ro Z ❑ ® at C O ro G C " Q C P' N = C 0 C x N vl V N M , t) N N N a c a, Zi c 00 0 0 en en rn c Z kl V o cra J F C E 0 CI) 7.. ° a V O U > 0 a._ A •,. tr, J E E a m'� _o a o E i o b N W Uzr .. '' W a E F O O G O '4 a s c -E " o a (I-) o0 o U' W C a L U : L C O C ` C C CO L c�� O '7 3 G it!. .E Q O V �. of S. oOCt "'7E m7 = W aorooE Inb.a.OU"'E 0_ c ��€ G. >.. c OU,0 c E c '.2 1WG s".UQaI 2 <n 7.2 c „J y A. W 0 d at 3 Vco S O at 0 a U _ O O N at 0 0 T T C 0 n L `n L 0 a . ti e 00 N W E N Q a ., Z Information m Section 04 — Stora T .0 Q z Actual While Controls Operational: External Floating Roof: Requested Permit Limit: m 30 c 9 O o H C 00 a) O Date Of First Production (Month/Year) v, 0 0 e Installation Date of most recent storage vessel in storage tank (Month/Year) nN, 0 N 4. Total Volume of Storage Tank (bbl) e N # of Liquid Manifold Storage Vessels in Storage Tank Z .0 0 N t7 " 00 a a 0 O F v = 0 See attached Addendum API Number d2 Fenn APCD-207-Produced W aterfank-APEN 0 m at FORM A PUD-207 h Emission Source AIRS II): Permit Number: 7 5 on 0 L .0 _ E u O 0 0 at 0 0 0 E VD E F °0 0 ANN U U O U C a N N 0 on C a) U t U o t 03 at C pp z,zqdv 0 �O 3 aQ z en C O d E W L CM a- 0 7 o > `) K O - Co F- Co at 73 lc: t >z CC r o m 0 m on 05 00 O E A e tn fec O GOCA Z; In O U in W Y 00 O0 0 v s m 0 c 0 re), ❑ 0 ® O d 0 n E E Y v 0 O Y N O o N w t C) � N v - : s o o - b G 9 O I c o o U 0 0 z .. v Cn Y H 0 00 O CJ 0- C V 0 a) E L d 0 a) C 0 m 7 00 C v v co a) at 0 W C S a N 0 ro0 z 77 v ❑ � o Make/Model: c o U 0 0 G O v C y v _ cm.0 v 47 -0 ocip a C 04 O s > 0 .L a) m c cr c at ° 0 N used for control o Describe Any Oth 5 m S 0 0 m C 0 00 F s '7, Y L con N L U C y O o%j O y _0 W v 4 at G t U O 0 0 °e° U O E 00 v 2 0 ° ti 0 0 y ti A v O C v 0 C G C t, ti L - .9 m v, E 8 0 O y w o y .r r at m O ^ a v O ° m O x t C7 t U m w v -- a to o = v, O 'z ° 3 a C O A C L Estimation Method or Emission Factor Source CDPHE Memo et ' y i CUP HE Memo E 0- x S a Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions CI 0 ` m 0 C O O 0.44 0 oC — o O O Uncontrolled (Tons/Year) Q Z 01 00 NA a 0 O 0 umentation attached Data year for actual calenuar yr. emtssmns oemw o 111101. gup... ... on.. o- .,. II ..,.- it Emission Factor Actual Calendar Year Emission Uncontrolled Controlled Uncontrolled Basis Units (Tons/Year) (Tons/Year) -0 .0 a ? a a -0 .0 0 0 o 0 • 0 o O 0 O q O O z O > O U v N 0.1 0 ❑ H Fthulhenzene 0 ' < v c 0 -t-,E c a c `a . F d C- 2 u O 0 R C Environmental Re y A J C U � C O O O O . m o a a at .F 3 0 0 0 a .0 o C 0 at h 0 0 O .0 v s k v v E— r,y :� J C L �'0 0 '0 t? 0 a c s O ¢ v U -O Tc� p 0 cd o v e d s 'VA E CJ -7 `' 5 5 .O 0 0 7 yw 3 z 5 O t .n ° v, ' ,c` ma 9 m c 'o 0.z1° a C ,`n 'P 2 9 O m • C U m d C s -CJ v 5 p F i 5. ° y T>1' Y 0 C ON a'' v m .�'0 ° E at v F .0 — . _q o 0 p -,h .. G C G O . 6 2 v L Q •_ .w T[z0. 0 v A u 1 u C a� .h 3 ? u ,2 r 0-,0 w Ti 4'z b C ° m <7-- zA 2-..9 N 8 v O W o ote id a -tr. U F y et c.9 r, .u7 O 0 F my £ . .F 0 = v o.3 c 7 c m 52. 0 0 0 0 .0 d2 Form APCD-207-ProducedWaterTank-Al O 0 00 m FORM APCD-207 E&P Storage Tank Air Pollutant Emissions Notice (APEN) Addendum Form' Company Name: Bonanza Creek Energy Operating Company, LLC Source Name: State Antelope CPF O-1 (COGCC# 440823) Emissions Source AIRS ID2: 123 / / Wells Services by this Storage Tank or Tank Battery (E&P Sites Only) API Number Name of Well Newly Reported Well 05 - 123 - 41151 State Antelope 24-1-36XRLNB VA 05 - 123 - 41147 State Antelope J-1-36XRLNB N. 05 - 123 - 41148 State Antelope J14-1-36CRLNC I 05 -123 - 41149 State Antelope J24-1-36XRLNC E 05 - 123 - 41150 State Antelope O24-1-36XRLNC a 05 - 123 - 41154 State Antelope T-1-36XRLNB I 05 - 123 - 41155 State Antelope Y-1-36XRLNB I 05 - 123 - 41159 State Antelope 44-1-36XRLNB I - - ❑ - ❑ - ❑ - . - ❑ - - - ❑ - - ❑ - - ❑ Footnotes: Attach this addendum to associated MEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 dl a Form APCD-212-EP-StorageTank-APEN-Addendum_ Condensate.docx R tNI L Ct z L Y O O L 0 021 O A a O z z O con z% Or Emission Source AIRS ID: igned a permit # & AIRS ID] [Leave blank unless APCD has already a dentify how this equipment is referenced within your organization.] [Provide Facility Equipment ID tt c. G cu E E .a 7 z L v C a 422 uested Action (check applicable request boxes) Section 02 — Re Section 01 — Administrative Information Request for NEW permit or newly reported emission source Request MODIFICATION to existing permit (check each box below that applies) Change fuel or equipment Change permit limit ❑ ❑ Request to limit HAPs with a Federally enforceable limit on PTE E ❑ D C a V 0 _ U U U ¢ Zcc Source Name: N z F a cc cc Source Location: P N 0 O 0 N O C0 C N O I= U ✓ y ❑• N 410 17th Street, Suite 1400 2 Denver, CO 720-305-0802 Fax Number: Section 03 — General Information N N CC r recovery towers is L Y y 3 r 3 a 3 V Z E O 4 O x Z rt.' a V V ho 0 C d WI as © E H J O C • n c r O_ O a u O C L2 V . � O CC C c o x € z n of equipment and purpose: General descri a rO.—�o m .n O h U U C O z L a • z!,6U aL C • o e > w oUo.� C • U a e D 0. c Qa z } esrd C cc 0 ¢_ Z _ E'° c U a t U S C c a U c> o o O O O E c 3 J 3 -.Ed- e Equipment Information Section 04— Processin Y C C 0 0 T2o E C a ' C C U v a!, o 0 o E.� LS') o C ° = 6 a C. — T E c 3 • L F U CG 0 ca ❑z❑❑❑ C G 0 a C N a C) C- 0. 0 0. U � O c ea 2- 0.0 rep 0 0 6 6 C n 6 CC C) a 0 a C U request copy A® A x a C 3 a N 7..! • 3 c 0. C co O 0 C M O U e e O N > 3 0 N t limitations. Requested level shall be Z G m UTo C z 0 C. C i FORM APCD-21I C a L R z E .O 0.0 O U cI O 0 W 0 Q CO CO F C z z C Gx� z ICI C N Emission Source AIRS ID: Permit Number: Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) 0 C) C) v F 0 is O 0 a U O O E L H .❑i 0 0 u a — E- o o ` U U O U N N O e N N N 0 r-' 3 q O cc —zoo -(a o oa 0 Z -- 7 C) N o¢ LL - c a N F c ^ '0 e 7 LL oc 0 U W n .H OC CO I e^ N 0 2 3 3 q 2 al a)0 > ❑ ` H U ® o a y L a a O � 1 Y c) a N v a a Q G v 00 v Io y C o O ^ P c o o - ❑ E 4 w a, •C o • 00 ^ CC Tr an 0 tn 0 0 0 0 o 00 °C kti It o It,e o 0 00 00 00 C Z CO 0 • O co ✓ N U o• In co 33 33 = - uo s: 00 a L z 0 W 0 L b 0 L a Make/Model/Serial IF: Enclosed Flare a U H Manufacturer Guaranteed: an Y 07) a N 0 U O > z 0 n LL O C) N S Make/Model: N ti w ) 15. LU G U a. 4 wu > y t U mT. Q O = T > m o c o 'E rf • m C; 7 i V P E a < O c 0 cop L 7 E,20 '‘f4 0 W c 0 E L ❑ 0 0 QT 0 E L ti> H ❑ C y = ❑ 0 a Estimation Method or Emission Factor Source Mass Balance AP42 Tb U.5 -I .0 e Mass Balance li Mass Balance Mass Balance Mass Balance Mass Balance Mass Balance Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions° Controlled (Tons/Year) 35.74 C ,O c 0 t— N 0 N O 0 N 0It) rw.0 0 N 0 N N O 0 Q ,0 0 0 M 0 Uncontrolled (Tons/Year) 0 00 Q TO 1— VM VNI < 7 3.348 0 Q N1 0 Q O 0 N - 00 v, O N Actual Calendar Year Emissions Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor Units V a.0.0 V a U F U� C. U En Uncontrolled Basis In N 0 CC) co 00 = 0 0- 0 O 0 In G M N vl t'1 o 1(1 v a N iC) t- N Control Efficiency (% Reduction) In Cr. 1! 0 VI 0 N 0 V) 0 VI 0 Overall Collection Efficiency 0 0 0 0 0 0 0 0 0 0 0 0 Control Device Description Secondary E ECD ECD 0 U ECD ECD 0 W G o VOC zU op N w U - u ". Po U x V S c C c cd R 0 '> 6 a F a • ❑ w> re v ° G v0 v T E z ;_ T j o.. •A aL J 'o a.H '. j o o v J -0 U rn d7 Donn APCD-211 Natural Gas Venting APEN ECD O 00 a FORM APCD-211 2 0 z U.! 0 0 Q W .n U E !- z O 0_ z co z O a O V! N w C o. Z Q ° o M N J c J -2 O O) ao 'icy; J 03 'a-, Q N II 0 a w U 0 Permit Number: Bonanza Creek Energy Operating Company, LLC Zip Code: 80202 C O 0 N CD SW/SE Sec. 1, T5N, a) E c ca o z.75 T O C O J O_ E c o 0 a JDismukes@BonazaCrk.com E-mail Address: Controlled Actual Emissions Ibs/ ear M O N N Uncontrolled Actual Emissions (lbs/year) 4,925.5 Emission Factor Source N d a Emission Factor (Include Units) 287.3 Ib/MMscf Control Equipment / Reduction (%) to rn Chemical Name 2,2,4-Trimethyl pentar Chemical Abstract Service (CAS) Number O to N 0 a) O) co C co 2 O 7 O) a) CO C a) E C O C W CD co 0 T O_ D_ cn O a) N O L -. Q N O) a) C O i Q) d O u) F- Name of Person Legally Authorized to Supply Data (Please print) Form Revision Date: April 14, 2014 n Liquid Loading' 123 / [Provide Facility Equipment ID to identify how this equipment is referenced within your organization.] uested Action (Check applicable request boxes) Section 02 — Re Section 01 — Administrative Information General Permit GP07 Individual Permit Action Applies To: O T C o E 0 0 m C O T o) 0 W m d U m N C N 0 a) CD oen 'a U U z cc e U U 0 C LL `o 0- a LL a O 0 Q an Source Name: N CD Z Lo F SW/SE Sec. 1, Source Location: M Change process or equipment -o 0 U Change permit limit 0 Denver, Colorado 3 0 a d a 9 a a 'E z� d 8 a C i e e o c P— V V N 0 0 U a N JDismukes@bonanzacrk.com E-mail Address: 720-305-0802 E 0 Addl. Info. & Notes: Section 03 — General Information days/week 52 Normal Hours of Source Operation: 11, 0 0 Loading of condensate into tanker trucks Don't know 00000 Z z ZZZ z ❑ o o❑o < < < Ya } 7 > ❑ ❑o❑ co T 0. N y C 0 C w m p v, r La N C 4 L y c E a a o, O 00 Co Gr o o o m C U O o C .o ao t. C _o o y -o -6- -o A a z 3. 0 w o m 0 > A , 0 cn 0 0 0 E O C � O 'E — (C 0 0. A e,9 ' S 7,�' oCt A C N p C O O 0 p o 4 C. m O Mp w0 a?< > > O J -r03 8 z <o >> w y 0 A C t' c C 0. 0 o -c `a .E 8 E o C m_o c v 'a _ R O2 O C a Er a E g 9,o a 0 _ n0. E' 0 N .T0 O a C a y -c .0 -a ._J -C 0c,°:' a s u o c o d e x 0 0 0 °p o E u C n n a 0 0 5 a 5 9 - o• y a_ .a C y C T., C a y> ` a O O L. L. n a 'o y y = " 'y a c L " 3 a Y a U ♦ ♦ ♦ ♦ < m z 0 P, VIa Q �, � rc, N N N P P a d D \0�c0 e M e< rt 0' e` 0 0 0 c' IA .e. T. I �a (A e C 2 0 W z .! eo w a t 0 6 z Cy < .E < C v a L a m a 11 V.z Z E V y N H > Ea m en o c o w C 0 o a o a '3 . W o 0 " a m m et o > O > n p O 2 V ''0 00E i`0 0 E.y 3 3 Ia..N L oQ 3 3 o. E .`a a.. U m o U 3 a s aC9 `O u °o_.c 7 y`Oo rn aU C . L C 9 up L t .2 a y. y= 2GU ' -q 02' z .. 0 oU0 bo a A A N '3 a p., V 0 E a �04UQe= a <O0 < a Tdo .n a 0 a n a 0 e a d M E (0 0 0 .. 0 e -.1 0 0 r -o O a # E c c 0 V C' C E ° ae J c 1 Z e > m 0 v v E g S C '- o `e a c ° o A a' _ H L V o.< E A i E o FORM APCD-208 FormAPCD-208-HydrocarbonLiquidLoadingAPEN-Ver.4-14-2014 (1).docx 0 00 a asul C CO GMM 11 O L U C 0 h. ea L Pw c` C7 O U o 7 't o f% U g C o O o v ..`0° Cu z .. w rs aN �.9 U • 'n O 1'- z� .. 0. Q a N 0 Cie a u I. 0 G C 00 E W Section 06 —Stack (Source, if no combustion) Location (Datum & either Lat/Long or UTM) u ✓ d a 7 E m C 0 0 L L m EO U zo • E is E m 5 ea Etz kin Y u O C CM N U U 0 O U N 0 CO r r 0 co co C z o g Jam. auC. 6 dm F m O m 0 U w C L 0 Section 08 — Emissions Inventory Information 0.l 0 0 F v c J co 'a O 0 C) N cc a N 0 U 0 Condensate c Ci 0 0 C) F 00 J oo a O 0 G N m co co ..1 0 0 4 U Data year for actual calendar year emissions below & throughput in Sec. 04 (e.g. 2007): 00 .e. 0 V 0. u 00 0 'O CY .44 C C m C E u 0 0 z R 0 E Estimation Method or Emission Factor Source AP -02 Tables 11.5-182 AP 42 Chap 5.2 AP -42 Tables 13 5-182 AP 42 Chap 5.2 AP 42 Chap 5.2 Please use the APCD Non -Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. Requested Permitted Emissions Controlled (Tons/Year) O O in O 0 LO CV O O c0 N O Uncontrolled (Tons/Year) 137.26 O CO r CJ N O CJ Actual Calendar Year Emissions' Controlled (Tons/Year) Uncontrolled (Tons/Year) Emission Factor e m m _ _ Uncontrolled Basis CO CD O O O rn CO NI - O N CO O O O O C) O O O I Control Efficiency (% Reduction) Identify in Section 07 Control Device Description Secondary 000 F. Pollutant o C O Z ›C) O N m v '0 00 L R r 0 Ed 00 L C 00 m m E E O 'L Environmental Regulatory Manager O 0. E u a 00 b OO c e 00 t 0. E 0 e E rn e a a CO V O a .- 1141 00 s ✓ 00 u L r 4 r fa, O 0 0 N 4 cr z m m • 0 0 c .0 _ 0 C T O. O m 0. C o • E y N L 0 C d w O cL. m "' O 00 a 2 O z w C 0 w c) F 0 z 0 U) U) 5 w I z La r J J 0 cc a co J a I- cc 0 a w cc NN LL w I 9 0 z E 0 r m a) a E O U C O U ca 5 a, a) N a) m a) a) 0) AIRS ID Number: Permit Number: Bonanza Creek Energy Operating Company, LLC Company Name: Zip Code: 80202 303-803-1724 c = E 0 7 U z a) c 0 L a SW/SE Sec. 1, T5N, R62W Plant Location: JDismukes@BonazaCrk.com E-mail Address: Controlled Actual Emissions Ibs/ ear M O M co N m N Uncontrolled Actual Emissions (lbs/year) 582.63 O co 0) co o) Emission Factor Source AP -42 AP -42 Emission Factor (Include Units) To O) O O O O co O O d 0.0064 lb/1,000-gal Control Equipment / Reduction (%) 95 95 Chemical Name 2,2,4-Trimethylpenta .tl a) C a) a 0 I- Chemical Abstract Service (CAS) Number r co (a U co co 0 o a) is 0 co s t0 CV o In a in 7 CD 0 Q O a a o a) o o'a = } 0 <I L — O m E J 3 ; c it O 7 C o a) co } N C T m m U .CT) a) a Environmental Regulatory Manager Title of Person Legally Authorized to Supply Data c .a co CL a) CO 0 T a a 7 U) 0 m N L 7 CO 0) m 0 a) a 0 (1) E co z O N 7 Form Revision Date: A Hello