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Home My WebLink About20151530.tiff 41/4 COPHE COLORADO CO Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 o St PO B RECEIVED PO Box 758 Greeley, CO 80632 MAY 222015 May 19, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On May 20, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company LLC - Pronghorn T-4. 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, wV Clara Gonzales j Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure cRU- J LCAZ 2015-1530 /..p-1 -15 aG-Pc:?03; 154V ....--O, 14.6,, r� 430C Cherry Creek Drive S., Denver, CO 80246-1530 P 303.692-2000 www.colorado.govicdphe :i.5 -= yc John W. Hickenlooper. Governor Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ,,, .:...:., \-t40-0,,'' CDPHE Air Pollution Control Division CO Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company LLC - Pronghorn T-4 - Weld County Notice Period Begins: May 20. 2015 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company LLC Facility: Pronghorn T-4 Oil and gas exploration and production facility SESW Sec 4, T5N, R61W Weld County The proposed project or activity is as follows: Source proposes to operate an oil and gas exploration and production facility The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • 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 13WE2590 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: Carissa Money Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us c o 1 I AV ::tr, ire. F STATE OF COLORADO of CO to •LORA D PARTM NT •F PUBLIC HEALTH AND ENVIRONMENT ae% AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 • t ,r.• }/at6 CONSTRUCTION PERMIT PERMIT NO: 13W E25590 Issuance 2 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the Pronghorn T-4 Production Facility, located in the SESW Section 4, Township 5N, Range 61W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Three (3) 500 bbl above ground atmospheric condensate storage CNDTK-1 002 tanks controlled by two enclosed flares. Each flare has a minimum control efficiency of 95%. One (1)400 bbl above ground produced water storage tank PW 003 controlled by two enclosed flares. Each flare has a minimum control efficiency of 95%. Hydrocarbon Loadout to Tanker Trucks. Loadout is controlled by TLO 004 using dedicated vapor balance service and two enclosed flares. Collection system is 70% efficient and each flare has a minimum control efficiency of 95%. Overall control efficiency is 66.5% One (1) pneumatic water transfer pump, rated at 600 scf/hr P-1 006 (Sandpiper, Model G1F, Serial number 1004984). The pneumatic pump is controlled by two enclosed flares. Each flare has a minimum control efficiency of 95%. One (1) pneumatic heat trace pump, rated at 600 scf/hr P-2 007 (Sandpiper, Model G1 F, Serial number 2010602). The pneumatic pump is controlled by two enclosed flares. Each flare has a minimum control efficiency of 95%. One vapor recovery tower(VRT) controlled by two enclosed VRT-1 011 flares during VRU downtime. Each flare has a minimum control efficiency of 95%. AIRS ID: 123/9B5E Page 1 of 18 Illolor Depa en . P •li ealth and Environment A ,it Pollution Control Division Facility Equipment AIRS Description ID Point One emergency flare used to combust separator gas during FL-2 012 emergencies or when the pipeline is not available. Flare has a minimum control efficiency of 95%. The flare is not enclosed. Two low-pressure separators controlled by two enclosed flares SEP-1 013 during VRU downtime. Each flare has a minimum control efficiency of 95%. Points 006 and 007: Each pump may be replaced with another pump in accordance with the provisions of the Alternate Operating Scenario (AOS) in this permit. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION ' 1. AIRS Point 012: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation, 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. AIRS Point 012: The following information shall be provided to the Division within fifteen (15) days after commencement of operation. • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 3. AIRS Point 012: Within one hundred and eighty days (180) after commencement of operation, 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). 4. AIRS Points 002 - 007 and 011 - 013: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, lay 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. AIRS ID: 123/9B5E Page 2 of 18 olor. Depa 4 en ` P li ealth and Environment it Pollution Control Division 5. AIRS Points ;01 : .mod,; .,z:L hundb-_:e..nd eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 6. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, Ill.F.4.) 7. AIRS Points 011 and 013: Within one hundred and eighty (180) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flowrate of natural gas vented from the low pressure separators and vapor recovery towers. The operator shall use the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed one hundred and eighty (180) days after issuance of this permit. 8. 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.) 9. 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 10. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO, VOC CO CNDTK-1 002 --- 0.6 --- Point PW 003 0.5 Point TLO 004 1.4 Point P-1 006 --- 2.1 1.3 Point P-2 007 --- 2.1 1.3 Point VRT-1 011 --- 0.4 --- Point FL-2 012 --- 3.9 2.4 Point AIRS ID: 123/985E Page 3 of 18 olor eepa en . P .Ii ealth and Environment •it Pollution Control Division SEP-1 (13 ' ' `" "' - '" . `".1 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. 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. 11. 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 CNDTK-1 002 Enclosed Flare VOC PW 003 Enclosed Flare VOC TLO 004 Vapor balance and Enclosed Flare VOC P-1 006 Enclosed Flare VOC P-2 007 Enclosed Flare VOC VRT-1 011 Enclosed Flare VOC FL-2 012 Open Flare VOC SEP-1 013 Enclosed Flare VOC PROCESS LIMITATIONS AND RECORDS 12. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID CNDTK-1 002 Condensate Throughput 83,220 BBL PW 003 Produced Water Throughput 74,460 BBL TLO 004 Condensate Loaded 83,220 BBL P-1 006 Venting of natural gas used to drive 5.3 MMSCF pneumatic pump AIRS ID: 123/985E Page 4 of 18 olor Depa en P li ealth and Environment it Pollution Control Division ti ur. ,yf<:... to dri P-2 °r 5.3 MMSCF pneumatic pump VRT-1 011 Total Gas Vented from the Vapor Recovery 0.1 MMSCF Tower(VRT)during VRU Downtime FL-2 012 Total Gas Vented from All Separators to 10 MMSCF Emergency Flare SEP-1 013 Total Gas Vented from Both Low-Pressure 2,5 MMSCF Separators during VRU Downtime 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. 13. AIRS Points 011 and 013: Upon installation of the flow meter required under Condition 7, the owner or operator shall continuously monitor and record the volumetric flowrate of natural gas vented from all low pressure separators and VRTs during VRU downtime using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented to the enclosed flares from all low-pressure separators and VRTs during VRU downtime. The owner or operator shall use monthly throughput records and calculation methods detailed in the O&M Plan to demonstrate compliance with the limits specified in Condition 12 and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 14. 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) 15. 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. (Reference: Regulation No. 1, Section II.A.1. & 5.) 16. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 17. AIRS Point 002: 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. 18. AIRS Point 002: 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. 19. AIRS Points 002, 003, 011, and 013: 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: AIRS ID: 123/9B5E Page 5 of 18 i olor. ■epa en . P .li '' ealth and Environment A °it Pollution Control Division M/II.B.2.b If .E. :_ sr- +e'' - u. +ntrol - 'r..sions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. 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: XVI1.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. 20. AIRS Points 002 and 003: 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. XVII.C.1.b.(i)(a) Control requirements of Section XVII.C.1.b. must be achieved by May 1, 2015. 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; AIRS ID: 123/9B5E Page 6 of 18 olor. Depa en • P li ealth and Environment it Pollution Control Division XVII.C 7 ». »>e iSkitainS+:=, C• of ig:w, n eolluti•,v =, trol 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. 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 a documented Storage Tank Emission Management System ('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 AIRS ID: 123/9B5E Page 7 of 18 olor. Depa . P 'Ii ealth and Environment A0 •it Pollution Control Division in - io ' in - -R �1) da - 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 Approved Instrument Phase-In Uncontrolled Actual VOC Monitoring Method Inspection Schedule Emissions (tpy) Frequency > 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 storage tanks and associated equipment at the 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. AIRS ID: 123/9B5E Page 8 of 18 olor. Depa, eni P li ealth and Environment it Pollution Control Division 4. wr XVII.C.3.f. A f4 ., .ui...1a=,rt - :a«-te. ;s Ft stor nk 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. 21. AIRS Point 004: This source is located in an ozone non-attainment or attainment- maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, II I.E) 22. AIRS Point 004: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with Condition 22 (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. 23. AIRS Point 004: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 24. AIRS Points 011, 012 and 013: The separation equipment, including low pressure separators and vapor recovery towers, covered by this permit is subject to Regulation 7, Section XVII.G emission control requirements. 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. 25. AIRS Point 012: The emergency flare, which receives gas from the separators during emergencies, is an approved alternative emissions control equipment per Regulation No. 7, Section XVII.B.2.e. The emergency flare shall comply with all applicable requirements in Regulation No. 7, Section XVII.B General Provisions (State only enforceable), except the flare is not required to be enclosed. OPERATING & MAINTENANCE REQUIREMENTS 26. 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.) 27. AIRS Point 004: The owner or operator of a loadout at which vapor balancing is used to control emissions shall: AIRS ID: 123/9B5E Page 9 of 18 olor- iepa= en * P .Ii '' ealth and Environment ill •it Pollution Control Division a. Install - =rat- ollk - -, retu • -uipment to coiled vapors during loading of tank compartments of outbound transport trucks and return these vapors to the stationary source storage tanks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. g. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 28. AIRS Point 011: The operator shall complete an initial site specific extended gas analysis of the gas vented from the vapor recovery towers at this site in order to verify VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. ALTERNATE OPERATING SCENARIOS 29. AIRS Points 006 and 007: This pump may be replaced with a like-kind pump in accordance with the requirements of Regulation 3, Part A, Section IV.A and without applying for a revision to this permit or obtaining a new construction permit. A like-kind replacement pump shall be the same make, model and capacity as authorized in this permit. 30. AIRS Points 006 and 007: The owner or operator shall maintain a log on-site or at a local field office to contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 31. AIRS Points 006 and 007: All pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 32. All previous versions of this permit are cancelled upon issuance of this permit. AIRS ID: 123/985E Page 10 of 18 olor Depa eri P: li ealth and Environment . g it Pollution Control Division • 33. This permit r poi hich are cancelled upon issuance of this permit. Existing Existing Permit No. Emission Point New Permit No. GP01 123/9B5E/002 13WE2590 Issuance 2 GP05 123/965E/003 13WE2590 Issuance 2 34. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 301h 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. 35. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 36. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II.B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee. AIRS ID: 123/985E Page 11 of 18 olor.: eepa : en P 'Ii ealth and Environment it Pollution Control Division it 37. If this permit all - e fin-' zatio 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. 38. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 39. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 40. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 41. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 42. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Carissa Money Permit Engineer AIRS ID: 123/9B5E Page 12 of 18 olor Depa en, P li ealth and Environment it Pollution Control Division Permit Histo re„" Issuance Date Description Issuance 2 This Issuance Modification to convert AIRS Point 002 from GP01 to this permit. Also increased throughput and emissions. Modification to convert Point 003 from GP05 to this permit. Also increase throughput and emissions. Modification to Point 004 to increase throughput and emissions and to add control. Cancellation of Point 005. Modification to Points 006 and 007 to decrease throughput and emissions. Adding new points 011 - 013. Issuance 1 April 21, 2014 Issued to Bonanza Creek Energy Operating Company LLC for Points 004 - 007 AIRS ID: 123/9B5E Page 13 of 18 1, olorl eepa en . P .li ealth and Environment it Pollution Control Division Notes to Permit Holder b ="'me o .e a 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these ' fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) • 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONW rapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s)operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (Ib/yr) Benzene 71432 98 No 5 n-Hexane 110543 608 Yes 30 002 Toluene 108883 86 No 4 Ethylbenzene 100414 10 No 0.5 Xylenes 1330207 37 No 2 Benzene 71432 521 Yes 26 003 n-Hexane 110543 1,638 Yes 82 Benzene 71432 49 No 16 n-Hexane 110543 496 Yes 166 004 Toluene 108883 39 No 13 Ethylbenzene 100414 3 No 1 Xylenes 1330207 7 No 2 Benzene 71432 184 No 9 n-Hexane 110543 1,054 Yes 53 006 Toluene 108883 138 No 7 Ethylbenzene 100414 21 No 1 Xylenes 1330207 53 No 3 AIRS ID: 123/9B5E Page 14 of 18 olor Depa ent P li ealth and Environment it Pollution Control Division Ben '� 4 34, 9 n-Hexane 110543 1,054 • Yes 53 007 Toluene 108883 138 No 7 Ethylbenzene 100414 21 No 1 Xylenes ' 1330207 53 No 3 Benzene 71432 145 No 7 n-Hexane 110543 879 Yes 44 011 Toluene 108883 119 No 6 Ethylbenzene 100414 12 No 1 Xylenes 1330207 45 No 2 Benzene 71432 350 Yes 18 n-Hexane 110543 2,006 Yes 100 012 Toluene 108883 263 Yes 13 Ethylbenzene 100414 39 No 2 Xylenes 1330207 101 No 5 Benzene 71432 72 No 4 n-Hexane 110543 433 Yes 22 013 Toluene 108883 37 No 2 Ethylbenzene 100414 9 ', No 0.5 Xylenes 1330207 17 I No 1 5) The emission levels contained in this permit are based on the following emission factors: Point 002: Uncontrolled Controlled lb/BBL lb/BBL Condensate Condensate Pollutant Throughput Throughput Source VOC 0.2916 0.0146 Promax n-Hexane 0.0073 0.0004 Promax Benzene 0.0012 _ 0.0001 Promax Toluene 0.0010 0.00005 Promax Ethylbenzene 0.0001 0.00001 Promax Xylenes 0.0004 0.00002 Promax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. A HHV of 2,302 BTU/scf was used for combustion calculations. Point 003: Pollutant I Uncontrolled I Controlled i Source AIRS ID: 123/9B5E Page 15 of 18 olor Depa en P .li '' ealth and Environment 4 ,i .it Pollution Control Division t = P c ./B- -,.r ed ._. Water Throughput Water Throughput VOC 0.262 0.0131 CDPHE n-Hexane 0.022 0.0011 CDPHE Benzene 0.007 0.0004 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 004: Uncontrolled Controlled lb/BBL Pollutant lb/BBL loaded loaded Source VOC 0.1006 0.0337 AP-42 Benzene 0.0006 0.0002 AP-42 n-Hexane 0.0060 0.0020 AP-42 Toluene 0.0005 0.0002 AP-42 Ethylbenzene 0.00004 0.00001 AP-42 Xylenes 0.0001 0.00003 AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95)using the following values: L= 12.46*S*P*M/T S = 1 (Submerged loading: dedicated vapor balance service) P(true vapor pressure)=2.49 psia M (vapor molecular weight)=47.51 Ib/Ib-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 stable condensate by the VOC emission factor. Points 006 and 007: Emission Emission Factors - Factors- Uncontrolled Controlled Pollutant Ib/MMscf vented lb/MMscf vented Source NOx 0.068 0.068 AP-42 (lb/MMBTU) CO 0.37 0.37 AP-42 (lb/MMBTU) VOC 15,622 781.12 Gas Analysis Benzene 35.036 1.7518 Gas Analysis n-Hexane 200.56 10.028 Gas Analysis Toluene 26.256 1.3128 Gas Analysis Ethylbenzene 3.9218 0.1961 Gas Analysis Xylenes 10.085 0.5042 Gas Analysis The displacement equation can found in "EPA Emission Inventory Improvement Program Publication: Volume II, Chapter 10- Displacement Equation (10.4-3)." Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,293 BTU/scf was used for combustion calculations. AIRS ID: 123/9B5E Page 16 of 18 olor Depa. en'of P .li ealth and Environment Mir Pollution Control Division Point 011: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled lb/MMscf lb/MMscf NOx ___ 0.068 0.068 AP-42 (lb/MMBTU) CO -__ 0.37 0.37 AP-42 (lb/MMBTU) VOC 81.3 101,358 5,067.9 Gas Analysis Benzene 0.8 1,057.9 52.897 Gas Analysis Toluene 0.7 868.44 43.422 Gas Analysis Ethylbenzene 0.1 90.272 4.5136 Gas Analysis Xylenes 0.3 325.28 16.264 Gas Analysis n-hexane 5.1 6,413.6 320.68 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated based on a Promax model to estimate the VOC and HAP content of the stream and stream flow. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 2,619 BTU/scf was used for calculations. Point 012: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled lb/MMscf Ib/MMscf NOx --- 0.068 0.068 AP-42 (Ib/MMBTU) CO ___ 0.37 0.37 AP-42 (lb/MMBTU) VOC 26.1 15,622 781.12 Gas Analysis Benzene 0.06 35.036 1.7518 Gas Analysis n-Hexane 0.34 200.56 10.028 Gas Analysis Toluene 0.04 26.256 1.3128 Gas Analysis Ethylbenzene 0.01 3.9218 0.1961 Gas Analysis Xylenes 0.02 10.085 0.5042 Gas Analysis Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,293 BTU/scf was used for calculations. Point 013: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled lb/MMscf lb/MMscf NOx ___ 0.068 0.068 AP-42 (lb/MMBTU) CO --- 0.37 0.37 AP-42 (lb/MMBTU) VOC 75.5 81,482 4,074.1 Gas Analysis Benzene 0.03 28.651 1.4325 Gas Analysis Toluene 0.01 14.588 0.7294 Gas Analysis Ethylbenzene 0.003 3.6417 0.1821 Gas Analysis Xylenes 0.01 6.7232 0.3362 Gas Analysis AIRS ID: 123/9B5E Page 17 of 18 olor. Depa en . P .li ealth and Environment •it Pollution Control Division it Fraction of Factors Factors Pollutant Gas (%) Uncontrolled Controlled Source lb/MMscf lb/MMscf n-hexane 0.16 172.81 8.6407 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated using weighted average of low pressure separator gas samples collected 11/6/2014 from Pronghorn T-4 VRU inlet to estimate the VOC and HAP content of the stream and a Promax model to estimate stream flow. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 2,321 BTU/scf was used for calculations. 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC NANSR Synthetic Minor Source of: VOC 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.q poaccess.qov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 163.1-63.599 Subpart A-Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT I 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart 7777—Subpart MMMMM MACT i 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: 123/9B5E Page 18 of 18 Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 05/06/2015 Application Date: 12/26/2014 Facility Identifiers Permit No. 13WE2590 Potentially located in ozone nonattainment area AIRS County# 123 Weld Facility# 9B5E Facility Type: exploration and production facility ❑' Located in the 8-hour non-attainment area? O True Minor Synthetic Minor for: P VOC (W NOx f' CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn T-4 Production Facility Source Location: SESW Section 4, Township 5N, Range 61W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address ity,State Zip: Denver,CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pyoung@bonanzacrk.com 'Requested Action Self Certification Required? Yes Issuance Number: 2 Source Description: Oil and gas exploration and production facility known as the Pronghorn T-4 Production Facility,located in the SESW Section 4,Township 5N,Range 61W,Weld County,Colorado. Point Name Type Control Action Cancelling GP01 and adding to facility-wide 002 CNDTK-1 Condensate Tanks Flare permit.Also modifying point by increasing throughput and emissions Cancelling GP05 and adding to facility-wide 003 PW Water Tanks Flare permit.Also modifying point by increasing throughput and emissions 004 TLO Loadout Flare Modifying by increasing throughput and adding control Existing point-In application (12/2014), source requested to increase counts and 005 FUG Fugitives None emission limit from 3.9 to 10.1 tpy. On 5/12/2015,source requested to cancel fugitives since subject to Reg 7 and now APEN-exempt 006 P-1 Pump Flare Modifying by decreasing throughput and emissions 007 P-2 Pump Flare Modifying by decreasing throughput and emissions 011 VRT-1 Separator Venting Flare New point-vapor recovery tower venting during VRU downtime 012 FL-2 Separator Venting Flare New point-emergency flare 013 SEP-1 Separator Venting Flare New point-Two LP separators venting during VRU downtime *Pt 001 is an engine covered by GP02 *Pts 008-010 are engines covered by GP02 Three(3)500 bbl above ground atmospheric condensate storage tanks controlled by two 002 enclosed flares. Each flare has a minimum control efficiency of 95%. Requsted Throughput 83220 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2916 lb/bbl 12.1 tpy 0.6 tpy Promax Benzene 0.0012 lb/bbl 98 lb/yr 5 lb/yr Promax n-Hexane 0.0073 lb/bbl 608 lb/yr 30 lb/yr Promax Toluene 0.0010 lb/bbl 86 lb/yr 4 lb/yr Promax Ethylbenze 0.0001 lb/bbl 10 lb/yr 0 lb/yr Promax Xylenes 0.0004 lb/bbl 37 lb/yr 2 lb/yr Promax 224-TMP 0.0011 lb/bbl 881b/yr 4 lb/yr Promax Nox 0.068 lb/Mmbtu 0.03 tpy 0.0 tpy AP-42 Table 1 CO 0.37 Ib/Mmbtu 0.2 tpy 0.2 tpy AP-42 Table 1 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. 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. The 500 bbl tanks are above the minimum capacity threshold of—471 bbl. However, the tanks are located at the wellhead site, store condensate, and are prior to custody transfer; thus, the tanks are exempt from NSPS Kb (60.110b(d)(4)). 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 the nonattainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is currently subject to this requirement since actual uncontrolled emissions are greater than 6 tpy. Tanks were constructed prior to 511/2014. 13WE2590.CP2 123/985E One(1)400 bbl above ground produced water storage tank controlled by two 003 enclosed flares. Each flare has a minimum control efficiency of 95%. • Emissions Calculations Requsted Throughput 74460 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 9.8 tpy 0.5 tpy CDPHE Benzene 0.007 lb/bbl 521 lb/yr 26 lb/yr CDPHE n-Hexane 0.022 lb/bbl 1638 lb/yr 82 lb/yr CDPHE Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60,Appendix A(July, 1992))in all subsections of Section II.A and B of this regulation. 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.1.b Applicant is subject since actual uncontrolled emissions are greater than 6 tpy. The storage tank was constructed prior to 5/1/2014. 13WE2590.CP2 123/9BSE Hydrocarbon Loadout to Tanker Trucks. Loadout is controlled by using dedicated vapor balance service and two enclosed flares.Collection system is 70%efficient and each flare has a 004 minimum control efficiency of 95%.Overall control efficiency is 66.5% Calculations L= 12.46*S*P*M/T(AP-42:Chapter 5.2, Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source 5 Saturation Factor 1 AP-42 factor for submerged loading,dedicated v, P True Vapor Pressure 2.49 psia Calculated TVP of liquid based on oil analysis an M Molecular Weight of Va 47.51 lb/lb-mole Calculated MW of liquid based on oil analysis an T Liquid Temperature 523.67 deg. R EPA Tanks Met Data for Denver, CO L 2.39 lb/10^3 gal 1.01E-01 lb/bbl Annual requested Throughput 83220 BBL/yr 228 BBI/day 3495240 gal/yr Annual requested VOC emissions 8369 lb/yr 4.18 tpy Control: Flare Efficiency: 66.50% Source assumes 95%control efficiency and 70%collection efficiency NCRPs Component Mass Fraction VOC 0.8507 Benzene 0.0058 n-hexane 0.0593 Toluene 0.0046 Ethylbenzen 0.0004 Xylenes 0.0009 Source: Sales oil composition and Eq 1-22 of AP-42 Ch 7 Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.1006 lb/bbl 4.2 tpy 1.4 tpy AP-42 Benzene 0.0006 lb/bbl 49 lb/yr 16 lb/yr AP-42 n-Hexane 0.0060 lb/bbl 496 lb/yr 166 lb/yr AP-42 Toluene 0.0005 lb/bbl 39 lb/yr 13 lb/yr AP-42 Ethylbenzen 0.00004 lb/bbl 3 lb/yr 1 lb/yr AP-42 Xylenes 0.0001 lb/bbl 7 lb/yr 2 lb/yr AP-42 13WE2590.CP2 123/9BSE Hydrocarbon Loadout to Tanker Trucks. Loadout is controlled by using dedicated vapor balance service and two enclosed flares.Collection system is 70%efficient and each flare has a 004 minimum control efficiency of 95%.Overall control efficiency is 66.5% Regulatory Review 'Regulation 3-APEN and Permitting Requirements Is this site considered an exploration and production location (e.g.well pad)? Yes If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons(238 BBLs)per day of crude oil on an annual average basis? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 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? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.I 13WE2590.CP2 123/985E 005 Fugitive equipment leaks AS OF 111/2015,THIS SITE IS SUBJECT TO REG 7.XV II.F.UNDER REG 55011 F.SOURCE CAN USE TABLE 2-9 EMISSION FACTORS. WITH TABLE 2.8.FUGITIVE EMISSIONS ARE NOW APEN•EXEMPT.SOURCE REQUESTED TO CANCEL APEN Regulation 7 Information Oner ting Hours. 8780 hours/year Emission Fador Source Screenirg EFs-EPM03Rd5-017 Taole 2-0 Control Eflm:ency Source. None Calculations Emission Factor(kglbr-I Emi ssions Service Component Type Count ice) Control(%el Pollutant Mass Fraction (g.le Table 1.0E-05 0.0005 Convectors 155, 2.O0EC0 5.00E-05 00% VOC 02011 0092522 CFlangesyst-S 50 390E-0a 5]OE05 00"5 Benzene 0]006 00002463 Gas Open Souls Lines 50 2.00E-03 1.50E-05 0 00% toluene O0001 00001463 E-SS Pump Seals 6 340E 03 3.50E-0a E-0% Elnyibenzene 00001 5.558E-05 Valves 2-S 450E03 150E05 .0e Xylenas 00002 7519E-05 Other '05 8.50E-03 120E-0a 0 0% n-Hexane 00030 00012459 Connectors O u0E-06 7.5➢E-06 00% VOL 1 Flanges 0 3.90E-07 390E-0E 0% Benzene Open-Ended Lines 0 140E-04 7.20E-06 00 Toluene Heavy Oil Pump Seals _ 00Ew0 0.00E+00 00°%% Emymenzene Valves 54 40E-06 S 40E-06 00% Xylenes I-Hexane Other r 3.20E-05 370E-05 006 nCtexane Connectors 490 250E-04 9]OE-06 00% VOC 09982 0782571 Flanges 20 LOSE-04 240E-06 0% Benzene 00053 00004155 cgnl0,1 Pump vexed Lines 2 1a0E03 140E-05 O0% Toluene 00135 0.0010662 PompSeals 0 530E-02 v0E-04 00 Pylons eve 0 O037 00002901 Valves 250E-03 1.90E-05 00% Xylenas 00155 00012387 Omer 17 7.5➢E-0 120Eaa 00% 0-Hexane 3032 00025007 Connectors 1]0E-0a 100E-05 0O% VOC 1 0 Flanges 2.90E-C6 290E-36 Benzene 0 Open-Ended Linea 250E-0a 350E-06 0 0% Toluene 0 water/on Pump Seals T40EC5 240E-05 0 7 Elhebenzene 0 Valves 9.80E-05 9.70E-06 00% Xylenas 0 Other 140E-02 SA0E-05 OOM n-Hexane 0 — Emissions Summary Table Pollutant Uncontrolled Emissions Oontr0l1ed Emissr0ns Source VOC 0.17 toy 0.171py Screening EFs•EPA-053/R-95•017 Table 2-8 Benzene 11b/yr I Iblyr Screening EFs-EPA-053/R-95-017 Table 2-0 Toluene 2 Ib/yr 2 lblyt Screening EFs-EPA-053/R-95-017 Table 2-0 Elnyl£emene 1 lb/yr IIb/yt Screening EFs-EPA-453/R-95-017 Table 2-0 Xylenas 310%. 31110r Scaeninq EFs-EPA-453R-95-017 Table 2-8 n-Heyene Blb/yr 9 Iblyr Screening EFs-EPA-453/R-95017 Table 2-8 Regulatory Applicability Reg 3 Renew Regulation 3.Part B.Beebe.III 0 210 determine is RACT is Rgulrea7 Yes Renew 40 CFR.Pad 60.Subpart KKK to determine it appliWole to this sours? No Regfi Renew 40 CFR.Pad 60,Subpart 0000 to determine it 80 9380 andIer 80.5365 is applicable? No Reg.7 Review Section XVl5F to determine is LOAR is applicable? yes One(1)pneumatic water transfer pump,rated at 600 scf/hr(Sandpiper, Model G1 F,Serial number 1004984).The pneumatic pump is controlled by 006 two enclosed flares.Each flare has a minimum control efficiency of 95%. Pump Information Manufactur Sandpiper Model Number:G1F Serial Pump Number:1004984 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control Flare 95.00%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation{10.4-31 Ex=CI*MW•Xx/C Ex=emissions of pollutant x O=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas•MW of air Xx=mass fraction of a in gas C=molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Q soo scf/hr MW 22.6716/16-mol Hours of oo. 6760 hourspr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy CO2 25474 44 0.0494 CO2 1.774 15544.114 7.772 nitrogen 3902: 28 0.0111 nitrogen 0.400 3504.074 1.752 methane 726453 16.04 0.5140 methane 18.447 161595.042 80.798 ethane 123821 30.07 0.1642 ethane 5.894 51634.964 25.817 propane 73933 44.09 0.1439 propane 5.165 45242.530 22.621 isobutane 37069 58.12 0.0182 isobutane 0.652 5713.822 2.857 n-butane 2.1361 58.12 0.0548 n-butane 1.965 17217.232 8.609 isopentane 33667 72.15 0.0117 isopentane 0.419 3669.132 1.835 n-pentane 04547 72.15 0.0145 n-pentane 0.519 4549.644 2.275 cyclopentane a 035 70.15 0.0011 cyclopentane 0.040 347.306 0.174 n-hexane 00662 86.18 0.0034 n-hexane 0.120 1054.123 0.527 cyclohexane 0025, 84.18 0.0009 cyclohexane 0.034 296.523 0.148 Other hexanes a.1so 86.18 0.0057 Other hexane. 0.205 1793.921 0.897 heptanes 00326 100.21 0.0028 heptanes 0.099 869.965 0.435 methylcyclohexa 30177 98.19 0.0008 methylcyclohe 0028 241.022 0.121 224-TMP 00018 114.22 0.0001 224-TMP 0.003 28.512 0.014 Benzene 0017 78.11 0.0006 Benzene 0.021 184.150 0.092 Toluene 33108 92.14 0.0004 Toluene 0.016 138.003 0.069 Ethylbenzene 0.0014 106.17 0.0001 Ethylbenzene 0.002 20.613 0.010 Xylenes 33036 106.17 0.0002 Xylenes 0.006 53.005 0.027 C8+Heavies 00429 116.23627 0.0022 C8+Heavies 0.079 691.536 0.346 Mass Fraction VOC: 0.2612 Total VOC 41.056 Heating Value I 1293 BTU/scf combustion emissan factor ource: AP-42:Chapter 13.5 3.37 I lb NoxoMMem 0.37 lb CO/MMBtu 13WE2590.CP2 123/9B5E One(1)pneumatic water transfer pump,rated at 600 scf/hr(Sandpiper, Model Cl F.Serial number 1004984).The pneumatic sump is controlled by 006 two enclosed flares.Each flare has a minimum control efficiency of 95%. mote Mole 15.MW,and mass fractions are based on weighted average of sales gas samples collected 7/23/2013 from T-P-IHNB end 11/5/2014 from 14-1 Emissions are based on 8760 hours of operation per year I calculated the average MW of 08 based on the average MW on the analysis for the gas. Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 15622 lb/MMscf /8112 lb/MMscf 41.1 tpy 2.1 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 Ib/MMBTU 0.2 tpy 0.2 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 1.3 spy 1.3 tpy AP-42 Benzene 35.0361h/MMscf 1.7518 lb/MMscf 1841b/yr 9 lb/Yr Gas Anaysis n-Hexane 200.56 lb/MMscf 10.028 lb/MMscf 1054 lb/yr 53 lb/yr Gas Analysis Toluene 26.256 lb/MMscf 1.3128 lb/MMscf 138 lb/yr 7 lb/yr Gas Analysis Ethylbenzene 3.9218 lb/MMscf 0.1961 lb/MMscf 211b/yr 1 lb/yr Gas Anaivsis Xylenes 10.085 lb/MMscf 0.5042 lb/MMscf 531b/yr 3 lb/yr Gas Analysis 13WE2590.CP2 123/985E One(1)pneumatic heat trace pump,rated at 600 scf/hr(Sandpiper,Model Cl F,Serial number 2010602).The pneumatic pump is controlled by two 007 enclosed flares.Each flare has a minimum control efficiency of 95%. Pump Information Manufactur Sandpiper Model Number:G1F Serial Pump Number:2010602 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptic Control Flare 95.00%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Qa MW'Xs/C Ex=emissions of pollutant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of s in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm O ens scf/hr MW 22 sr lb/lb-mol Hours prop. 8790 eoursyr Requested Throughput 5.256 MMsd/yr Component mole% MW mass fraction Component lb/hr lb/yr toy CO2 25474 44 0.0494 CO2 1.774 15544.114 7.772 nitrogen 09024 28 0.0111 nitrogen 0.400 3504.074 1.752 methane 726453 16.04 0.5140 methane 18.447 161595.042 80.798 ethane 123821 30.07 0.1642 ethane 5.894 51634.964 25.817 propane 7.3993 44.09 0.1439 propane 5.165 45242.530 22.621 isobutane 07089 58.12 0.0182 isobutane 0.652 5713.822 2.857 n-butane 2.1361 58.12 0.0548 n-butane 1.965 17217.232 8.609 isopentane ?3997 72.15 0.0117 isopentane 0.419 3669.132 1.835 n-pentane 04547 72.15 0.0145 n-pentane 0.519 4549.644 2.275 cyclopentane 00357 70.15 0.0011 cyclopentane 0.040 347.306 0.174 n-hexane 0 0582 86.18 0.0034 n-hexane 0.120 1054.123 0.527 cyclohexane 00254 84.18 0.0009 cyclohexane 0.034 296.523 0.148 Other hexanes 01501 86.18 0.0057 Other hexane 0.205 1793.921 0.897 heptanes 30626 100.21 0.0028 heptanes 0.099 869.965 0.435 methylcyclohexa 70177 98.19 0.0008 methylcyclohe 0.028 241.022 0.121 224-TMP 0 sole 114.22 0.0001 224-TMP 0.003 28.512 0.014 Benzene 0017 78.11 0.0006 Benzene 0.021 184.150 0.092 Toluene 00108 92.14 0.0004 Toluene 0.016 138.003 0.069 Ethylbenzene 70014 106.17 0.0001 Ethylbenzene 0.002 20.613 0.010 Xylenes 00036 106.17 0.0002 Xylenes 0.006 53.005 0.027 C8+Heavies 30429 116.23627 0.0022 C8+Heavies 0.079 691.536 0.346 Mass Fraction VOC: 0.2612 Total VOC 41.056 Heating Value I 1293 BTU/scf Combustion emission favor 9ovn;e: AP-42:Chapter 13.5 0.07 I lb NOXIMMetu 0 37 m co7MMetu • 13WE2590.CP2 123/985E One(1)pneumatic heat trace pump.rated at 600 scf!hr(Sandpiper.Model Gt F.Serial number 2010602).The pneumatic pump is controlled by two 007 enclosed flares.Each flare nas a minimum control efficiency of 95%. Notes Mole%,MW,and mass fractions are based on weighted average of sales gas samples collected 7(23/2013 from T_PANNB and 11/5/2014 from 14-1 Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+based on the average MW on the analysis for the gas. Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 15622 lb/MMscf 781.12 lb/MMscf 41.1 tpy 2.1 tpy Gas Analysis Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.2 tpy 0.2 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 1.3 tpy 1.3 tpy AP-42 Benzene 35.036 lb/MMscf 1,7518 lb/MMsd 1841b/yr 9 lb/yr Gas Analysis n-Hexane 200.56 lb/MMscf 10.028 lb/MMscf 1054 lb/yr 53 lb/yr Gas Analysis Toluene 26.256 lb/MMscf 1.3128 lb/MMscf 138 lb/yr 7 lb/yr Gas Analysis Ethylbenzene 3.9218 lb/MMscf 0.1961 lb/MMscf 21 lb/yr 1 lb/yr Gas Analysis sylenes 10.085 lb/MMscf 0.5042 lb/MMscf 53 lb/yr 316/yr Gas Analysis 13WE2590.CP2 123/985E One vapor recovery tower(VRT)controlled by two enclosed flares during VRU downtime.Each flare has a minimum 011 control efficiency of 95%. Equipment Description This source vents natural gas from: vapor recovery tower when the VRU is down Emissions from this source are: routed to a flare Natural gas venting from vapor recovery tower when the VRU is down.Emissions from this source are muted 10 a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q'MW•Xx/C Ex=emissions of pollutant x o=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mot)at 60F and 1 atm Throughput(0) 0.137 MMscf/yr 15.63926941 scf/hr MW 47.2785 Ibttb-mol 0.000375342 MMscf/d mole% MW Ibxltbmol mass fraction Ib/hr lb/yr try Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 1 74 44.01 0.766 0.016 0.03 276.95 0.14 N2 0.54 28.013 0.150 0.003 0.01 54.31 0.03 methane 1978 16.041 3.173 0.067 0.13 1146.98 0.57 ethane 15.88 30.063 4.774 0.101 0.20 1725.85 0.86 propane 23.17 44.092 10.214 0.216 0.42 3692.31 1.85 isobutane - 3.42 58.118 1.990 0.042 0.08 719.47 0.36 n-butane 1363 58.118 7.923 0.168 0.33 2863.88 1.43 isopentane 3.05 72.114 2.203 0.047 0.09 796.33 0.40 n-pentane 4.06 7?114 2.926 0.062 0.12 1057.59 0.53 cydopentane 1.28 70.13 0.900 0.019 0.04 325.18 0.16 n-Hexane 2.82 86.18 2.431 0.051 0.10 878.66 0.44 cydohexane 0.89 84.16 0.750 0.016 003 271.04 0.14 Other hepanes 527 86.18 4.540 0.096 0.19 1641.24 0.82 heptanes 1.74 100.21 1.745 0.037 0.07 630.64 0.32 methylcyclohexane 0.63 98.19 0.620 0.013 0.03 224.19 0.11 224-TMP 0.16 114.23 0.184 0.004 0.01 66.44 0.03 Benzene 0.51 78.12 0.401 0.008 0.02 144.94 0.07 Toluene 0.36 92.15 0.329 0.007 0.01 118.98 0.06 Ethvlbenzene 003 106.17 0.034 0.001 0.00 12.37 0.01 Xylenes 0.12 106.17 0.123 0.003 0.01 44.56 0.02 08+Heavies 0.91 121.0632911 1.102 0.023 0.05 398.22 0.20 VOC mess frac 0.813 Total VOC(Uncontrolled) 6.94 Notes Stream composition is based on Promax results for the VRT stream Flowrate is based on Promax results,assuming 15%downtime for VRU and applying 20%safety factor. 13WE2590.CP2 123/9B5E One vapor recovery tower(VRT)controlled by two enclosed flares during VRU downtime.Each flare has a minimum 011 control efficiency of 95%. Flaring Information Equipment Description Flare to combust VRT gas when the VRU is down. Manufacturer Leed Model Serial Number Gas Heating Value 2619 Btu/scf Throughput 358.803 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress VRT gas to sales line.The VRU is considered pan of the process and not included as an air pollution control device. Make Model Requested Control Efficiency Annual Bypass Time Backup J Flare 'Overall Control J 95.00%1 Combustion emission factor source: AP-42:Chapter 13.5 0.07 jib NOX/MMBtu 0.37 IIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 1013581b/MMscf 5067.9 lb/MMscf 6.9 tpy 0.3 tpy Gas Analysis Alex 0O71b/MMBTU 0.0716/MMBTU 0.0 tpy 0.0 tpy AP-42 CO 0371b/MMBTU 0.371b/MMBTU 0.1 spy 0.1 spy AP-42 Benzene 1057.9 lb/MMscf 52.897 lb/MMscf 145 lb/yr 7 lb/yr Gas Analysis n-Hexane 6413.6 lb/MMscf 320.68 lb/MMscf 879 lb/yr 44 lb/yr Gas Analysis Toluene 868 44 43.422 lb/MMscf 119 lb/yr 6 lb/yr Gas Analysis Ethylbenzene 90.272 lb/MMscf 4.5136 lb/MMscf 121b/yr 1 lb/yr Gas Analysis %ylenes 325.28 lb/MMscf 16.264 lb/MMscf 45 lb/yr 2 lb/yr ens Analysis 224-TMP 484.98 lb/MMscf 24.2491b/MMscf 66 lb/yr 3 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation I This source is subject to the opacity requirements for flares in Section 11 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.' AOCC 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." AOCC 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 XVILG.and control requirements of Reg 7,Section XVII.B.2 13WE2590.CP2 123/9BSE One emergency flare used to combust separator gas during emergencies or when the pipeline is not 012 available.Flare has a minimum control efficiency of 95%. The flare is not enclosed. Equipment Description This source vents natural gas from: a well head separator when the sales gas pipeline is not available or during emergencies Emissions from this source are: routed to a flare INatural gas venting from a well head separator when the sales gas pipeline is not available or during emergencies.Emissions from this source are routed to Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(104-3) Ex=O'MW*Xx/C Ex=emissions of pollutant x O=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SO of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Throughput(0) 10 MMscf/yr 1141.552511fscf/hr MW 22.67 lbllb-mol 002739726IMMscf/d mole% MW Ibx/Ibmol mass fraction Ib/hr lb/yr tpy Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.5474 44.01 1.121 0.049 3.38 29580.76 14.79 N2 - 09024 28.013 0.253 0.011 0,76 6669.90 3.33 methane 7.6453 16.041 11.653 0.514 35.10 307467.88 153.73 ethane 123821 30.063 3.722 0.164 11.21 98217.17 49.11 propane 11993 44.092 3.262 0.144 9.83 86081.78 43.04 isobutane 0 089 58.118 0.412 0.018 1.24 10870.67 5.44 n-butane 2'.361 58.118 1.241 0.055 3.74 32758.16 16.38 isopentane 02867 72.114 0.264 0.012 0.80 6977.36 3.49 n-pentane 04547 72.114 0.328 0.014 0.99 8651.78 4.33 cyclopentane 00357 70.13 0.025 0.001 0.08 660.59 0.33 n-Hexane 00882 86.18 0.076 0.0034 0.23 2005.56 1.00 cyclohexane 00254 84.16 0.021 0.001 0.06 564.03 0.28 Other hexanes 0.1501 86.18 0.129 0.006 0.39 3413.09 1.71 heptanes a 0626 100.21 0.063 0.003 0.19 1655.18 0.83 metylcyclohexane 10177 98.19 0.017 0.001 0.05 458.57 0.23 224-TMP 30616 114.23 0.002 0.000 0.01 54.25 0.03 Benzene 0017 78.12 0.013 0.0006 0.04 35041 0.18 Toluene 00108 92.15 0.010 0.0004 0.03 262.59 0.13 Elhylbenzene 7.0012. 106.17 0.001 00001 0.00 39.22 0.02 Xylenes 1.0036 106.17 0.1304 0.0002 0.01 100.85 0.05 Cat Heavies s 0429 118.1945921 0.050 0.002 0.15 1315.24 0.66 VOC mass frac 0.261 Total VOC(Uncontrolled) 78.11 Notes Mole%,MW.and mass fractions are based on weighted average of sales gas samples collected 7/23/2013 from T-P-4HNB and 11/5/2014 from 14-11-4HNB I calculated the average MW of C8+based on the average MW on the analysis for the gas. 13WE2590.072 123/9B5E One emergency flare used to combust separator gas during emergencies or when the pipeline is not 012 available.Flare has a minimum control efficiency of 95%. The flare is not enclosed. Flaring Information Equipment Description Flare to combust separator gas when ipeline is not available or during emergencies. Manufacturer TBD Model TBD Serial Number TED Gas Heating Value 1293 Btu/scf Throughput 12930 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Make Model Requested Control Efficiency Annual Bypass Time Backup Flare Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 jIb NOX/MMBtu 0.37 [lb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 15622 lb/MMscf 781.0916/MMscf 78.1 tpy 3.9 my Gas Analysis Nox 0.07 lb/MMBTU 0.071E/MMBTU 0.4 tpy 0.4 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 24 spy 2.4 spy AP-42 Benzene 35.04 lb/MMscf 1.75 lb/MMscf 350 lb/yr 18 lb/yr Gas Analysis n-Hexane 200.56 lb/MMscf 1002713 lb/MMscf 2006 lb/yr 100 lb/yr Gas Analysis Toluene 26.259 lb/MMscf 1.3130 lb/MMscf 263 lb/yr 13 lb/yr Gas Analysis Ethyl benzene 3.922 lb/MMscf 0.1961 lb/MMscf 39 lb/yr 2 lb/yr Gas Analysis Xylenes 10.085 lb/MMscf 0.50421b/MMscf 101 lb/yr 5 lb/yr Gas Analysis 224-TMP 5.425 tb/MMscf 0.271316/MMscf 54 lb/yr 3 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air" AOCC 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 However,since this flare is used for emergency purposes,not used routinely,and must control high pressure,high volume flow intermittently.the emergency flare will be approved as an alternative control device per Reg 7,Sec XVII B 2.e.The flare will have to meet Reg 7,Sec XVII.B except that it is not required to be enclosed 13WE2590.CP2 123/9135E Two low-pressure separators controlled by two enclosed flares during VRU downtime.Each flare has a 013 minimum control efficiency of 95%. Equipment Description This source vents natural gas from: low-pressure separators during VRU downtime Emissions from this source are: routed to a flare I Natural gas venting from low-pressure separators during VRU downtime.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume It.Chapter 10-Displacement Equation(104-3) Ex=O'MW'Xx/C Ex=emissions of pollutant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mgt)at 60F and 1 atm Throughput(0) 2.50443144 MMscf/yr 285.894 scf/hr MW 40.9 Ib/b-mcl 0.006861456 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr Ib/yr tpy Helium 000 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 0.95 44.01 0.41] 0.010 0.31 2]56.3] 1.38 N2 141 28.013 0.396 0.010 0.30 2618.]5 1.31 methane 6.47 16.041 1.037 0.025 0.78 6853.15 3.43 ethane 27.03 30.063 8.127 0.199 6.13 53704.93 26.85 propane 48.06 44.092 21.191 0.518 15.99 140031.05 70.02 isobutane 3.91 58.118 2.271 0.056 1.71 15008.04 7.50 n-butane 10.04 58.118 5.833 0.143 4.40 38544.16 19.27 isopentane 0.89 72.114 0.643 0.016 0.48 4248.26 2.12 n-pentane 0.89 72.114 0.639 0.016 0.48 4221.10 2.11 cyclopentane 0.04 70.13 0.029 0.001 0.02 189.07 0.09 n-Hexane 0.08 86.18 0.065 0.0016 0.05 432.80 0.22 cydohexane 0.02 84.16 0.021 0.001 0.02 136.25 0.07 Other hexanes 0.16 86.18 0.137 0.003 0.10 902.05 0.45 heptanes 0.01 100.21 0.011 0.000 0.01 75.49 0.04 methylcyclohexane 0.01 98.19 0.010 0.000 0.01 68.13 0.03 224-TMP 001 114.23 0.006 0.0001 0.00 39.25 0.02 Benzene 0.01 78.12 0.011 0.0003 0.01 71.75 0.04 Toluene 0.01 92.15 0.006 0.0001 0.00 36.54 0.02 Ethylbenzene 0.00 106.17 0.001 000003 0.00 9.12 000 Xylenes 0.00 106.17 0.003 0.0001 0.00 16.84 0.01 08+Heavres 0.00 116 0.006 0.000 0.00 36.79 0.02 VOC mass frac 0.755 Total VOC(Uncontrolled) 102.03 Notes Mole%,MW,and mass fractions are based on weighted average of low-pressure separator gas samples collected 11/5/2014 from Pronghorn T-4 Flowrate is based on Promax model,assuming 15%VRU downtime and applying a 20%safety factor MW of C8+is assumed to 116 13WE2590.CP2 123/965E Two Icw-pressure separators controlled by two enclosed flares during VRU downtime.Each flare has a 013 minimum control efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure separator gas during VRU downtime. Manufacturer Leed Model Serial Number Gas Heating Value 2321 Btu/scf Throughput 5812785372 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line.The VRU is considered part of the process and not included as an air pollution control devio Make Model Requested Control Efficiency Annual Bypass Time Backup Flare Overall Control I 95.00% Combustion emission factor source: AP-42.Chapter 13.5 0.07 lIb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 01482 lb/MMsd 4074.11 lb/MMscf 102.0 spy 5.1 tpy Gas Analysis Nos 0.071b/MMBTU 0.07 lb/MMBTU 0.2 tpy 0.2 toy AP-42 CO 0.371b/MMBTU 0.37 lb/MMBTU 1.1 tpy 1.1 any AP-42 Benzene 28.651 lb/MMsd 1.4325 lb/MMsct 72 lb/yr 4 lb/yr Gas Analysis n-Hexane 172.811b/MMscf 3.6407 lb/MMscf 433 lb/yr 22 lb/yr Gas Analysis Toluene 14.5881b/MMsd 0.7294 lb/MMscf 37 lb/yr 216/yr Gas Analysis Ethylbenzene 3.6421b/MMscf 0.1821 lb/MMscf 9 lb/yr 0 lb/yr Gas Analysis Xylenes 67231b/MMscf 0,3362 lb/MMscf 17 lb/yr 1 lb/yr Gas Analysis 224-TMP 15.6➢3 lb/MMscf 07836 lb/MMscf 39 lb/yr 2 lb/yr Gas Analysis Regulatory Applicability AOCC Regulation 1 This source is subject to the opacity requirements for flares in Section 11.4.5'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions i into the atmosphere of any air pollutant which is in excess of 30%opacity' AOCC 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" AOCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? Y.. This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 13WE2590.CP2 123/9B5E AIRS(Oouny/Plant)123/965E Permit No.13WE2590 Date 5/62015 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions CM. reportable Point 4 SCC Pollutant or CAS Factor Emisison Factor Source (tpy)* (tpy)' PTE(tpy) Eft% VOC 6.9420 lb/1000 ga Promax 0.5 0.6 12.1 95% Yes NOx 006801WMmblu AP-42 Table 13.5 0.0 0.0 0% No CO 0.3700 lbIMmblu AP-42 Table 13.5 0.2 0.2 0% No_ _ 002 40400311 Benzene 0.0282 lb//000 ga Promax 4 5 98 95% No n-Hexane 0.1739 lb/1000 qa Promax 25 30 608 95% Yes Toluene 0.0246 lb/1000 ga Promax 4 4 86 95% No Emylbenzene 0.0028 lb/1000 ga Promax 0 0 10 95% No Xylenes 0.0105 lb/I000 ga Promax 2 2 37 95% No VOC 6238 lb/1000 ga CDPHE 0.5 9.8 95% Yes 003 40400315 Benzene 0.167 511000 ga CDPHE 26 521 95% Yes n-Hexane 0.524 lb/1000 ga CDPHE 82 1638 95% Yes VOC 2.3945 lb/1000 ga AP-42 1.4 4.2 66.5% Yes Benzene 0.0139 lb/1000 ga AP-42 16 49 66.5% No 004 40600132 n-Hexane 0.1420 lb/1000 ga AP-42 166 496 66.5% Yes Toluene 0.0111 lb/1000 ga AP-42 13 39 66.5% No Ethytbenzene 0.0010 lb/1000 ga AP-42 1 3 86.5% No -- ylenes 0.0021 lb/1000 ga AP-42 2 7 66.5% No VOC 156221b/MMscf�Gas Analysis 2.1 41.1 95% Yes NOx 0.068 Ib/MMBTU AP-42 0.2 0.2 0% No CO 0.37 lb/MMBTUAP-42 1.3 1.3 0% Yes Benzene 35.036 lb/MMscf Gas Analysis 9 184 95% No 006 31000299 n-Hexane 200.56 lb/MMscf Gas Analysis 53 1054 95% Yes Toluene 26258 lb/MMscf Gas Analysis 7 138 95% No Elb benzene 3.92181b/MMscf Gas Analysis 1 21 95% No 6 -- -__ genes 10085 lb/MbIscf Gas Analysis 3 53 95% No VOC 15622 lb/MMscf Gas Analyses 2.1 41.1 95% Yes NOx 0.068 lb/MMBTU AP-42 0.2 0.2 0% No CO 0.370 lb/MMBTU AP-42 1.3 1.3 0% Yes 007 31000299 Analysis 350361NMMsnf Gas naysis 9 184 95% No n-Hexane 200.56 lb/MMscf Gas Analysis 53 1054 95% Yes Toluene 26.256 Gas Analysis ] 138 95% No Elhylbenzene 3.9218 lb/MMscf Gas Analysis 1 21 95% No Xylenes 10.085 b/MMscf Gas Analysis 3 l 53 95% No VOC 1013581WMMscf Gas Analysis 0.3 6.9 95% Yes NOx 0068 lb/MMBTU AP-02 0.0 0.0 0% No AIRS(County/Plant)123/965E Permit No.13WE2590 Cate 5/5/2015 Controlled Controlled Actual Requested NGRP= Uncontrolled Emission Emissions Emissions Ctrl. reportable Point SCC Pollutant or CAS Factor Emisison Factor Source (tpv)' (tpyJ' PTE(toy)* Eff% CO 0.37 lb/MMBTU AP-42 0.1 0.1 0% No 11 31000205 Benzene 1057 9 Ib/MMscf Gas Analysis 7 145 95% No o-Hexane 6413.6 lb/MMscf Gas Analysis 44 079 95% Yes Toluene 86844 Ib/MMscf Gas Analysis 6 119 95% No Ethylbenzene 902721b/MMscf Gas Analysis 1 12 95% No Xylenes 325281b/MMscf Gas Analysis 2 45 95% No VOC 15622 I5iMMscf Gas Analysis 3.9 78.1 95% Yes NOx 00681NMMBTU AP-42 0.4 0.4 0% No CC 0.3715/MMBTU AP-42 2.4 2.4 0% Yes Benzene 35041 Ib/MMscf Gas Analysis 18 350 95% Yes 12 31000205 o-Hexane 200.561b/MMscf Gas Analysis 100 2006 95% Yes Toluene 2625915/MMscf Gas Analysis 13 263 95% Yes Ethylbenzene 3.9218 lb/MMscf Gas Analysis 2 39 95% No ylenes 10.085 lb/MMscf Gas Analysis 5 101 95% No VOC 0.069 lb/MMscf Gas Analysis 5.1 95% Nos COx O0.37 Ib/MMBTU AP-42 1.1 0.2 0% No CO .651 lb/MMBTU AP-42 s 1.1 1 0% Yes 13 31000205 Benzene 172.911b/MMscf Gas Analysis 4 72 95% No n-Hexane 172011b/MMstl Gas Analysis 22 433 95% Yes Toluene 14.5881b/MMscf Gas Analysis 2 37 95% No Ethylbenzene 3.64171b/MMstl Gas Analysis 0 9 95% No X lanes 672321b/MMscf Gas Analysis 17 95% No 3 s u a v ,� a o o 0 u c ec" c N e▪ O a " 3 o z zz a. p_ c eeE E ^G`y\ omv, Y C L 0. a Yv ' Q s u F I❑.se®❑ u r o e,°, o a v`> en rn en = Y u ❑ m N Y 1:3 1N0 V y '� > ; z V Y a° a e m E ;70. w o 4o u u aaOZ _ F; 0 0 ° _en en en C ene:Di lal N u Y e .W \ >- >." >." a. e v 0. r yNj y C en en en o n en≤ - u m a Y '; . 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