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Home My WebLink About20151693.tiff CDPHE COLORADO Co Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St RECEIVED PO Box 758 Greeley, CO 80632 JUN 0 8 2015 June 2, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On June 3, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Bonanza Creek Energy Operating Company. LLC - Pronghorn T-3 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, lr Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 6- 1O-15- C.0i' P(.,�i,J; 43 2015-1693 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 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-3 Production Facility - Weld County Notice Period Begins: June 3, 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-3 Production Facility Oil and gas exploration and production facility SESE Sec 3 T5N R61 W Weld County The proposed project or activity is as follows: Source proposes to operate a new 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 13WE2615.CP2 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 AVCOt.OR?DO a 1 1 IAA �. 3 STATE OF COLORADO 9f it 9..�:' A:N VI g COLORADO DEPARTMENT •F PUBLIC HEALTH AND ENVIRONMENT 'k) -T-PTO AIR POLLUTION CONTROL DIVISION y o TELEPHONE: (303) 692-3150 *1876 ` CONSTRUCTION PERMIT PERMIT NO: 13WE2615 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-3 Production Facility, located in the SESE Section 3, Township 5N, Range 61W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment AIRS Point Description ID Three (3) 500 bbl above ground atmospheric condensate CNDTK-1 002 storage 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%. One (1)Arrow, Model A-62, Serial Number 6612004121, natural gas-fired, naturally aspirated, 4SRB reciprocating E2 004 internal combustion engine, site rated at 80 horsepower at 1800 RPM. This engine is equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio controller. This emission unit is a pump jack engine. Hydrocarbon Loadout to Tanker Trucks. Loadout is controlled by using dedicated vapor balance service and two TLO 005 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 heat trace pump, rated at 600 scf/hr P-2 008 (Sandpiper, Model G1F, Serial number 2004232). The pneumatic pump is controlled by two enclosed flares. Each flare has a minimum control efficiency of 95%. AIRS ID: 123/9839 Page 1 of 25 olorA sepa en • P '•li ealth and Environment •it Pollution Control Division .�i •..iii'. i ypi !t0. Facility Equipment AIRS Point Description ID One emergency flare used to combust separator gas during FL-2 014 emergencies or when the pipeline is not available. Flare has a minimum control efficiency of 95%. The flare is not enclosed. One vapor recovery tower(VRT) controlled by two enclosed VRT-1 016 flares during VRU downtime. Each flare has a minimum control efficiency of 95%. SEP-1, Two low-pressure separators controlled by two enclosed SEP-2 017 flares during VRU downtime. Each flare has a minimum control efficiency of 95%. One (1) pneumatic water transfer pump, rated at 600 scf/hr P-1 018 (Sandpiper, Model G1F, Serial number 2181394). The pneumatic pump is controlled by two enclosed flares. Each flare has a minimum control efficiency of 95%. AIRS Point 004: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow A-62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. AIRS Points 008 and 018: 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 014: 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 014: 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.) AIRS ID: 123/9839 Page 2 of 25 ate ftl olor � Depa en Pain ealth and Environment it Pollution Control Division ay 3. AIRS Point o4 in a igtb days ,4) 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. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at 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. 5. AIRS Points 002, 003, 005, 016 —018: Within one hundred and 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 016 and 017: 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 Equipment ID Point N0x VOC CO Emission Type CNDTK-1 002 --- 1.5 --- Point AIRS ID: 123/9639 Page 3 of 25 olor Depa en • P''.li ealth and Environment it Pollution Control Division ar � ri E IOll � y' PW "' 103 '" ' ..:'` -- Point E2 004 2.2 --- 3.7 Point TLO 005 1.7 Point P-2 008 --- 2.7 1.3 Point FL-2 014 --- 5.1 2.5 Point VRT-1 016 --- 1.7 0.3 Point SEP-1, SEP-2 017 --- 1.4 0.4 Point P-1 018 --- 2.7 1.3 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 E2 004 Non-Selective Catalytic Reduction System and NOx and CO air/fuel ratio controller TLO 005 Vapor balance and Enclosed Flare VOC P-2 008 Enclosed Flare VOC FL-2 014 Open Flare VOC VRT-1 016 Enclosed Flare VOC SEP-1, 017 Enclosed Flare VOC SEP-2 P-1 018 Enclosed Flare VOC AIRS ID: 123/9639 Page 4 of 25 p' �1,olora Depa enrof P lic'Health and Environment yt r it Pollution Control Division 112 ,c'Y Illnx 44 +1 1 .e.. • PROCESS LIMITATIONSAND`RECORDS ter = x'n:n 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 I 002 Condensate Throughput 127,020 BBL PW I 003 Produced Water Throughput 113,880 BBL E2 I 004 Consumption of natural gas as fuel 6.3 MMscf/yr TLO 005 Condensate Loaded 127,020 BBL P-2 008 Venting of natural gas used to drive 5.3 MMSCF pneumatic pumps FL-2 014 Total Gas Vented from All Separators to 10 MMSCF Emergency Flare VRT-1 016 Total Gas Vented from the Vapor Recovery 0.7 MMSCF Tower(VRT) during VRU Downtime SEP-1, 017 Total Gas Vented from Both Low-Pressure 1.4 MMSCF SEP-2 Separators during VRU Downtime P 1 018 Venting of natural gas used to drive 5.3 MMSCF pneumatic pumps 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 016 and 017: 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) AIRS ID: 123/9839 Page 5 of 25 olor Depa en P li ealth and Environment it Pollution Control Division • 17. AIRS Point 0,. ar a thi subj 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 Point 002: The condensate 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: XVII.C.1.a. Beginning May 1, 2008, owners or operators of all atmospheric condensate storage tanks with uncontrolled actual emissions of volatile organic compounds equal to or greater than 20 tons per year based on a rolling twelve-month total shall operate air pollution control equipment that has an average control efficiency of at least 95%for VOCs on such tanks. 20. AIRS Points 002, 003, 016 and 017: 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 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: 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. XVI1.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. 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. AIRS ID: 123/9639 Page 6 of 25 olorDepa ens P lid Health and Environment I' !1 t Mir Pollution Control Division °°3 ''� R XVII.O ' CQi€tl m:,- :o 3ectiond t.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; 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 a documented Storage Tank Emission Management System ("STEM") plan to AIRS ID: 123/9B39 Page 7 of 25 olor Depa en . P *II "" ealth and Environment it Pollution Control Division identi =te y e co* '; 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 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. AIRS ID: 123/9639 Page 8 of 25 zg m 114 olora ." Depa lenigf Pr lic ealth and Environment 311 a g : it Pollution Control Division aj 4 'far E 5 XVII.C.3. Recoilikeeffinga, a a `�r 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. AIRS Point 005: 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) 23. AIRS Point 005: 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 23 (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. AIRS Point 005: 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. 25. AIRS Points 014, 016 and 017: The separation equipment, including low pressure separators and vapor recovery towers, covered by this permit is subject to Regulation 7, AIRS ID: 123/9B39 Page 9 of 25 Ill 0104 Depa en . P till ealth and Environment t a it Pollution Control Division mi` e � Section XVII. L, n •. o m- , xm a-,.r aftr gust 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. 26. AIRS Point 014: 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 27. 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 28. AIRS Point 016: 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 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. Periodic Testing Requirements 29. AIRS Point 004: This engine may be subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ALTERNATE OPERATING SCENARIOS 30. AIRS Points 008 and 018: Each 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. 31. AIRS Points 008 and 018: 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. AIRS ID: 123/9639 Page 10 of 25 �olor tDepar en I P IidgHealth and Environment ` n m it Pollution Control Division ilrg 'Jo „sat " of Iii 32. AIRS Points takited °LUAID. c,. retilaants inaillied and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit. ADDITIONAL REQUIREMENTS 33. All previous versions of this permit are cancelled upon issuance of this permit. 34. This permit replaces the following permits and/or points, which are cancelled upon issuance of this permit. Existing Existing Permit No. Emission Point New Permit No. GP01 123/9B39/002 13WE2615 Issuance 2 GP05 123/9B39/003 13WE2615 Issuance 2 35. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 301b whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or AIRS ID: 123/9B39 Page 11 of 25 olor Depa en • P .li '` ealth and Environment s it Pollution Control Division operat-m. -.''er s '- -ma,1'.r ating r-- ario and is installing a permanent replacement engine. 36. 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 37. 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. 38. 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. 39. 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. 40. 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. 41. 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. 42. 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 AIRS ID: 123/9B39 Page 12 of 25 wern- ,.�. oloral Depar)1en!rof P- li ealth and Environment ka >R !?air Pollution Control Division 10, 'S a H , �J Division in wntkfbr estinttaa i' 3nciklati ` ermiapon notification, annual fee billing will terminate. 43. 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 Permit History 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 005 to increase throughput and emissions and to add control. Cancellation of Point 006 and 007. Modification to Point 008 to decrease throughput and emissions. Adding new points 014, 016 - 018. Issuance 1 November 21, Issued to Bonanza Creek Energy Operating 2014 Company LLC. Emission points covered under this permit include: one pump jack engine, condensate truck loadout, fugitive equipment leaks, and two pneumatic pumps. AIRS ID: 123/9B39 Page 13 of 25 3 ;a;y I olor Depa en . P .li ealth and Environment i Ir Pollution Control Division `�. SY r t Notes to Permit Holder �Fk=' 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=12515993896418ioaoename=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. 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 527 Yes 26 002 Toluene 108883 97 No 5 Ethylbenzene 100414 10 No 1 Xylenes i 1330207 22 No 1 Benzene 71432 797 Yes 40 003 n-Hexane 110543 2,505 Yes 125 Formaldehyde 5000 139 No 139 Methanol 67561 20 No 20 Acetaldehyde 75070 18 No 18 • 004 Acrolein 107028 17 No 17 Benzene 71432 11 No 11 1,3-Butadiene 106990 4 No 4 Toluene t 108883 3 No 3 Benzene 71432 64 No 22 005 n-Hexane 110543 612 Yes 205 Toluene 108883 44 No 15 AIRS ID: 123/9B39 Page 14 of 25 il ith t 4olora Depa en 6f P lil ealth and Environment I k k goj tkir Pollution Control Division a ...A 4.0 4 ' a ;e¢ =. 1.. % �' 2 Xylenes 1330207 7 No I 2 Benzene 71432 105 I No 5 n-Hexane 110543 574 Yes 29 008 Toluene 108883 112 No 6 Ethylbenzene 100414 21 No 1 I. Xylenes 1330207 47 No 2 Benzene 71432 200 No 10 n-Hexane 110543 1,091 Yes 55 014 Toluene 108883 214 No 11 Ethylbenzene 100414 39 No 2 Xylenes 1330207 90 No 4 Benzene 71432 272 Yes 14 n-Hexane 110543 1,435 Yes 72 016 Toluene 108883 251 Yes 13 Ethylbenzene 100414 22 No 1 Xylenes 1330207 49 No 2 I Benzene 71432 53 No 3 n-Hexane I 110543 354 Yes 18 017 Toluene I 108883 40 No 2 Ethylbenzene 100414 10 No 1 Xylenes I 1330207 16 No 1 Benzene 71432 105 No 5 n-Hexane 110543 574 Yes 29 018 Toluene I 108883 112 No 6 Ethylbenzene l 100414 21 No 1 Xylenes 1330207 47 I No 2 5) The emission levels contained in this permit are based on the following emission factors: Point 002: Uncontrolled Controlled Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput VOC 0.4650 0.0232 Promax n-Hexane 0.0042 0.0002 Promax Benzene 0.0008 0.00004 Promax AIRS ID: 123/9839 Page 15 of 25 olor.r Depa en P •li ' ealth and Environment it Pollution Control Division i ,xYf, `it . Pollutant lb/BBL Ib/BBL Source Condensate Condensate Throughput Throughput Toluene 0.0008 0.00004 Promax Ethylbenzene 0.0001 0.000004 Promax Xylenes 0.0002 0.00001 Promax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. A HHV of 2,292 BTU/scf was used for combustion calculations. Point 003: Uncontrolled Controlled lb/BBL Produced lb/BBL Produced Pollutant Water Throughput Water Throughput Source 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: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.9197 14.7000 0.7466 2.8000 CO 1.5465 5.8000 1.2799 4.8000 VOC 0.0107 0.0400 0.0107 0.0400 5000 Formaldehyde 0.0240 0.0900 0.0240 0.0900 67561 Methanol 0.0031 0.0115 0.0031 0.0115 75070 Acetaldehyde 0.0028 0.0105 0.0028 0.0105 107028 Acrolein 0.0026 0.0099 0.0026 0.0099 71432 Benzene 0.0016 0.0059 0.0016 0.0059 106990 1,3-Butadiene 0.0007 0.0025 0.0007 0.0025 108883 Toluene 0.0006 0.0021 0.0006 0.0021 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8268 Btu/hp-hr, a site-rated horsepower value of 80, and a fuel heat value of 918 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EF Source Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 5000 Formaldehyde Manufacturer Manufacturer 67561 Methanol AP-42; Table 3.2-3(7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3(7/2000); No Control AIRS ID: 123/9839 Page 16 of 25 ' 1 ;olora IDepa eni Of P li'Health and Environment Lot I '4 lAir Pollution Control Division IA A CAS �ant :e oll ,.. rce la,Controlled EF Source Natural Gas I 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas Point 005: Uncontrolled Controlled lb/BBL Pollutant lb/BBL loaded loaded Source VOC 0.0788 0.0264 AP-42 Benzene 0.0005 0.0002 AP-42 n-Hexane 0.0048 0.0016 AP-42 Toluene 0.0004 0.0001 AP-42 Xylenes 0.0001 0.00002 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)= 1.72 psia M (vapor molecular weight)= 51.17 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 008 and 018: Emission Factors Emission Factors- - Uncontrolled Controlled Pollutant lb/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 20,231 1,011.5 Gas Analysis Benzene 19.991 0.9996 Gas Analysis n-Hexane 109.15 5.4573 Gas Analysis Toluene 21.394 1.0697 Gas Analysis Ethylbenzene 3.9218 0.1961 Gas Analysis Xylenes 8.9642 0.4482 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 1,373 BTU/scf was used for combustion calculations. Point 014: 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(lb/MMBTU) 0.37 0.37 AP-42 AIRS ID: 123/9639 Page 17 of 25 h � olor. Depa en . P .li ' ealth and Environment 3 it Pollution Control Division js Fraction of Factors Factors Pollutant Gas(%) Uncontrolled Controlled Source lb/MMscf lb/MMscf VOC 31.9 20,229 1,011.5 Gas Analysis Benzene 0.03 19.994 0.9997 Gas Analysis Toluene 0.03 21.396 1.0698 Gas Analysis Ethylbenzene 0.01 3.9218 0.1961 Gas Analysis Xylenes 0.01 8.9642 0.4482 Gas Analysis n-hexane 0.17 109.15 5.4573 Gas Analysis Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,373 BTU/scf was used for calculations. Point 016: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled lb/MMscf lb/MMscf NOx(Ib/MMBTU) --- 0.068 0.068 AP-42 CO(lb/MMBTU) --- 0.37 0.37 AP-42 VOC 79.7 92,745 4,637.2 Gas Analysis Benzene 0.32 367.72 18.386 Gas Analysis Toluene 0.29 339.42 16.971 Gas Analysis Ethylbenzene 0.03 29.974 1.4987 Gas Analysis Xylenes 0.06 65.831 3.2916 Gas Analysis n-hexane 1.67 1,942.1 97.106 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 2,459 BTU/scf was used for calculations. Point 017: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled lb/MMscf Ib/MMscf NOx 0b/MMBTU) --- 0.068 0.068 AP-42 (Ib/ CO(Ib/MMBTU) --- 0.37 0.37 AP-42 VOC 49.2 39,487 1,974.4 Gas Analysis ', Benzene 0.05 37.926 1.8963 Gas Analysis Toluene 0.04 28.691 1.4345 Gas Analysis Ethylbenzene 0.01 7.2834 0.3642 Gas Analysis Xylenes 0.01 11.205 0.5603 Gas Analysis n-hexane 0.31 252.40 12.620 Gas Analysis Note: The uncontrolled VOC and HAP emissions were calculated using weighted average of low pressure separator gas samples collected 11/19/2014 from Pronghorn P-10-15 XRLNB VRU inlet to estimate the VOC and HAP content of the stream and a Promax model to estimate stream flow. AIRS ID: 123/9B39 Page 18 of 25 r _? � w y lairaq irolora Depar-10 en or P l kg n't �-lealth and Environment si Waal.W _ it Pollution Control Division irm Emission factorsacw0Cand tn.,ar Ald on,SP--4aTable 13 0':a-A HHV of 1,715 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) AIRS Point 004: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr181a08.pdf 8) AIRS Point 004: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.clov/ttn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC NANSR Synthetic Minor Source of: VOC 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: httn://ecfr.groaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories I — MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—SubpartDDD MACT 63.1200-63.1439 I Subpart EEE—Subpart PPP MACT I 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT I 63.6580-63.8830 Subpart 2777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN —Subpart XXXXXX AIRS ID: 123/9639 Page 19 of 25 olor Depa en P ili ealth and Environment •it Pollution Control Division 11) Ab self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.nov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9839 Page 20 of 25 war,‘ arta 4 ,olora Depar men?fsf PL, and Environment 1� r L_ .ir Pollution Control Division Jy ;H a gl a L6 V IT, T : 9 ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9639 Page 21 of 25 t olor A Depa r' en . P .h ealth and Environment •it Pollution Control Division I? r 2.1.2 The owner or o. z,a::r._`' y a` epl„• • "g-i isting r.'.ressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOx) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven(7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer)as found on the Division's web site at: http://www.colorado.qov/cs/Satellite/CDPH E-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year)or short term (lbs/unit of time)emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies)in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9839 Page 22 of 25 olor dtDepa=. en, P IiciHealth and Environment re' fr1/4 a :aptir Pollution Control Division j1! � . t— fi For comparison with a,i 1 li a ii.aiogther i (lb/M4040, output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOx and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOx and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOx or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOx and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine 2.3.1 Reasonably Available Control Technology(RACT): Reg. 3, Part B § 11.0.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOx are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOx and SO2, as precursors to PM1o, if the potential to emit of NOx or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC:The emission limitations in NSPS JJJJ CO:The emission limitations in NSPS JJJJ NOx: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM1a: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§ 60.331) and 40 CFR Part 72 (§72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9B39 Page 23 of 25 olor. Depa en . P .li " ealth and Environment a s it Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards:Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date x NO CO VOC January 1, 2008 2.0 " 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Pad B, § LB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart 7777 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart 7777. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9B39 Page 24 of 25 Ls ArA 11 •` ; c„ ;olora, ,'.Depar=nen P lic'Health and Environment gq- food Y `1 „II it Pollution Control Division '.a 3 requirements for the permanent eo9Rne r ac�ment,$l9al( included;in the Applicability Reports required under Condition 2,12. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division. provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9B39 Page 25 of 25 Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 05/12/2015 Application Date: 01/20/2015 Facility Identifiers Permit No. 13W E2615 Potentially located in ozone nonattainment area County 123 Weld AIRS Facility 9B39 Facility Type:exploration and production facility I]Located in the 8-hour non-attainment area? O True Minor Synthetic Minor for: P VOC F NOx i^ CO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Pronghorn T-3 Production Facility Source Location: SESE Section 3,Township 5N,Range 61W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address ty,State Zip: Denver,CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pvoung@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-3 Production Facility,located in the SESE Section 3,Township 5N,Range 61W,Weld County,Colorado. Point Name Type Control Action Cancelling GP01 and adding to facility-wide Condensate 002 CNDTK-1 Flare permit.Also modifying point by increasing Tanks throughput and emissions Cancelling GP05 and adding to facility-wide 003 PW Water Tanks Flare permit.Also modifying point by increasing throughput and emissions Modifying by increasing throughput and 005 TLO Loadout Flare adding control Modifying by decreasing throughput and 008 P-2 Pump Flare emissions 014 FL-2 Separator Venting Flare New point-emergency flare New point-vapor recovery tower venting 016 VRT-1 Separator Venting Flare during VRU downtime SEP-1,SEP Separator Venting Flare New point-Two LP separators venting 017 2 during VRU downtime 018 P-1 Pump Flare New Point `Pt 001 was an engine covered by GP02 but canceled 4/2015 `Pt 004 is a pump jack engine covered by Permit 13W E2615.It is not being modified so will remain in the permit 'Pt 006 was for Fugitive Equipment leaks which the source requested to cancel 02/11/2015 *Pt 007 was removed and new pump replacement,which was not like-kind replacement,is covered under Pt 018 *lots 009,011 and 012 are engines covered by GP02. Pt 009 was canceled 9/2014 'Pts 010 and 013 are permit-exempt engines `Pt 015 was for a temporary flare that was removed 11/9/2014 • 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 127020 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.4650 lb/bbl 29.5 tpy 1.5 tpy Promax Benzene 0.0008 lb/bbl 98 lb/yr 5 lb/yr Promax n-Hexane 0.0042 lb/bbl 527 lb/yr 26 lb/yr Promax Toluene 0.0008 lb/bbl 97 lb/yr 5 lb/yr Promax Ethylbenze 0.0001 lb/bbl 10 lb/yr 0 lb/yr Promax Xylenes 0.0002 lb/bbl 22 lb/yr 1 lb/yr Promax 224-TMP 0.0006 lb/bbl 77 lb/yr 4 lb/yr Promax Nox 0.068 lb/Mmbtu 0.07 tpy 0.1 tpy AP-42 Table 1 CO 0.37 lb/Mmbtu 0.4 tpy 0.4 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 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 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 20 tpy and greater than 6 tpy.Tanks were constructed prior to 5/1/2014. 13WE2615.CP2 123/9839 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 113880 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.262 lb/bbl 14.9 tpy 0.7 tpy CDPHE Benzene 0.007 lb/bbl 797 lb/yr 40 lb/yr CDPHE n-Hexane 0.022 lb/bbl 2505 lb/yr 125 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. 13WE2615.CP2 123/9839 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 005 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 S Saturation Factor 1 AP-42 factor for submerged loading,dedicated v; P True Vapor Pressure 1.72 psia Calculated TVP of liquid based on oil analysis an M Molecular Weight of Vaf 51.17 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 1.88 lb/10^3 gal 7.88E-02 lb/bbl Annual requested Throughput 127020 BBL/yr 348 BBI/day 5334840 gal/yr Annual requested VOC emissions 10008 lb/yr 5.00 tpy Control: Flare Efficiency: 66.50% Source assumes 95%control efficiency and 70%collection efficiency • NCRPs Component Mass Fraction VOC 0.8958 Benzene 0.0064 n-hexane 0.0611 Toluene 0.0044 Ethylbenzen 0.0005 Xylenes 0.0007 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 0.0788 lb/bbl 5.0 tpy 1.7 tpy AP-42 Benzene 0.0005 lb/bbl 64 lb/yr 21 lb/yr AP-42 n-Hexane 0.0048 lb/bbl 612 lb/yr 205 lb/yr AP-42 Toluene 0.0003 lb/bbl 44 lb/yr 15 lb/yr AP-42 Ethylbenzen 0.0000 lb/bbl 5 lb/yr 2 lb/yr AP-42 Xylenes 0.0001 lb/bbl 7 lb/yr 2 lb/yr AP-42 13WE2615.CP2 123/9839 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 005 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 11.0.1.1 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 11.0.1.1 • 13WE2615.CP2 123/9B39 One(1)pneumatic heat trace pump,rated at 600 scf/hr(Sandpiper,Model G1 F,Serial number 2004232).The pneumatic pump is controlled by two 008 enclosed flares.Each flare has a minimum control efficiency of 95%. Pump Information Manufactur Sandpiper Model Number CIF Serial Pump Number:2004232 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 sd/hour used consumptio Control Flare 95.00%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Cr MW*Xx/C Ex=emissions of pollutant x O=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=56 of gas"MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas 13]9 scf/Ih-moll at 60F and 1 a[m O ass scf/hr MW 24.02 Ib/Ib-mol Hours crap. 8760 heurshr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr Ib/yr toy CO2 24753 44 0.0453 CO2 1.724 15104.163 7.552 nitrogen 0.574 28 0.0067 nitrogen 0.254 2228.877 1.114 methane a9 6756 16.04 0.4653 methane 17.693 154989.125 77.495 ethane 12931E 30.07 0.1619 ethane 6.156 53926.034 26.963 propane 51196 44.09 0.1490 propane 5.667 49646.756 24.823 isobutane 05679 58.12 0.0210 isobutane 0.798 6994.576 3.497 n-butane 2905 58.12 0.0679 n-butane 2.581 22608.649 11.304 isopentane a 7212 72.15 0.0217 isopentane 0.824 7216.194 3.608 n-pentane 11548 72.15 0.0350 n-pentane 1.330 11652.773 5.826 cyclopentane oases 70.15 0.0017 cyclopentane 0.065 572.033 0.286 n-hexane 0 048 86.18 0.0017 n-hexane 0.065 573.672 0.287 cyclohexane 00126 84.18 0.0004 cyclohexane 0.017 147.094 0.074 Other hexanes 04374 86.18 0.0157 Other hexane 0.597 5227.589 2.614 heptanes 00416 100.21 0.0017 heptanes 0.066 578.123 0.289 methylcyclohexa 00114 98.19 0.0005 methylcyclohe 0.018 155.235 0.078 224-TMP 30007 114.22 0.0000 224-TMP 0.001 11.088 0.006 Benzene 30097 78.11 0.0003 Benzene 0.012 105.074 0.053 Toluene 30088 92.14 0.0003 Toluene 0.013 112.447 0.056 Ethylbenzene a e614 106.17 0.0001 Ethylbenzene 0.002 20.613 0.010 Xylenes 30032 106.17 0.0001 Xylenes 0.005 47.116 0.024 C8+Heavies 00619 150 0.0020 C8.Heavies 0.076 663.587 0.332 Mass Fraction VOC 0.3192 Total VOC 53.166 Heating Value I 1373 BTU/scf combustion omission(actor source: AP-42:Chapter 13.5 0.07 I lb NOWMMBlu 0.37 lb CO/MMBIu 13WE2615.CP2 123/9839 One(1)pneumatic heat trace pump.rated at 600 sef/hr(Sandpiper.Model G1 F,Senai number 2004232).The pneumatic pump is controlled by two 008 enclosed flares.Eacn flare nas a minimum control efficiency of 95%. Notes Mole Pe,MW.and mass fractions are based on weighted average of sates gas samples collected 7123/2013 from Pronghorn TP3MNB and 11/19/201, Emissions are based on 8750 hours of operation per year. Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 20231 Ih/MMscf 1011.5 lb/MMscf 53.2 tpy 2.7 tpy Gas Analysis Nos 007 Ib/MMBTU 0.07 Ib/MMBTU 0.2 tpy 0.2 tpy AP-42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 1.3 tpy 1.3 tpy AP-42 Benzene 19.991 lb/MMscf 0.9996 lb/MMscf 105 lb/yr 5Ib/yr Gas Analysis n-Hexane 109.15 lb/MMscf 5.4573 lb/MMscf 574 lb/yr 29 lb/yr Gas Anaivs15 Toluene 21.394lb/MMscf 1.0697 lb/MMscf 112 lb/yr 616/yr Gas.Nralvsis Ethylbenzene 3.9218 lb/MMscf 0.1961 lb/MMscf 21 lb/yr 3lb/yr Gas Analysis xylenes 8.9642 lb/MMscf 0.4482 lb/MMscf 47 lb/yr 2 Ib/yr Gas Anarysis 13WE2615.CP2 123/9839 One emergency flare used to combust separator gas during emergencies or when the pipeline is not 014 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(10.4-3) Ex=0*MW*Xx/C Ex=emissions of pollutant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air • Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mot)at 60F and 1 atm Throughput(0) 10 MMscf/yr 1141.552511 scf/hr MW 2402 lb/lb-mol 0.02739726 MMscf/d mole% MW Ibxllbmol mass fraction lb/hr Ib/yr tpy Helium 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 24753 44.01 1.089 0.045 3.28 28743.52 14.37 N2 0.574 28.013 0.161 0.007 0.48 4242.60 2.12 methane 69.6756 16.041 11.177 0.465 33.66 294898.76 147.45 ethane 129315 30.063 3.888 0.162 11.71 102575.11 51.29 Propane 8.1190 44.092 3.580 0.149 10.78 94461.58 47.23 isobutane 6 6678 58.118 0.504 0.021 1-52 1330734 6.65 n-butane 0605 58.118 1.630 0.068 4.91 4301345 21.51 isopentane 072'0 72.114 0.520 0.022 1.57 13722.59 6.86 n-pentane 1 164 72.114 0.840 0.035 2.53 22159.36 11.08 cydopentane 00588 70.13 0.041 0.002 0.12 1088.03 0.54 n-Hexane 0.048 86.18 0.041 0.0017 0.12 1091.46 0.55 cyclohexane 00126 84.16 0.011 0.000 0.03 279.79 0.14 Other hexanes 0.4374 86.18 0.377 0.016 1.14 9945.95 4.97 hectares 00418 100.21 0.042 0.002 0.13 1099.93 0.55 methylcyclohexane 0.0114 98.19 0.011 0.000 0.03 295.35 0.15 224-TMP 00007 114.23 0.001 0.0000 0.00 21.10 0.01, Benzene 00097 78.12 0.008 0.0003 0.02 199.94 0.10 Toluene 00066 92.15 0.008 0.0003 0.02 213.96 0.11 Ethyl benzene ..gam 106.17 0.001 0.0001 0.00 39.22 0.02 Xylenes 0.0032 106.17 0.003 0.0001 0.01 89.64 0.04 C8+Heavies 3.0319 150 0.048 0.002 0.14 1262.53 0.63 VOC mass frac 0.319 Total VOC(Uncontrolled) 101.15 Notes Mole 16,MW,and mass fractions are based on weighted average of sales gas samples collected 7/23/2013 from Pronghorn TP3HNB and 11/19/2014 from Pronghorn P-10- • 13W52615.0P2 123/9539 One emergency flare used to combust separator gas during emergencies or when the pipeline is not 014 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 TBD Gas Healing Value 1373 Btu/scf Throughput 13730 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 IIb NOX/MMBtu 037 IIb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 202291b/MMscf 1011.5 lb/MMscf 101.1 tpy 5.1 tpy Gas Analvsls Nus 0.07 lb/MMBTU 0.07 lb/MMBTU 0.5 spy 0.5 toy AP-42 CO 0.37 lb/MMBTU 0.37 Ib/MMBTU 2.5 spy 2.5 spy AP-42 Benzene 19.994 lb/MMscf 0.999716/MMscf 200 lb/yr 10 lb/yr Gas Analysis n-Hexane 10915 lb/MMscf 5.4573 lb/MMscf 1091 lb/yr 55 lb/yr Gas Anaiyas Toluene 21.396 lb/MMscf 1.0698 lb/MMscf 214 lb/yr 51 lb/yr Gas Analysis Ethylben2ene 3.92181b/MMscf 01965 lb/MMscf 39 lb/yr 2 lb/yr Gas Analysis xylenes 8.9642 lb/MMscf 0.4482 lb/MMscf 901b/yr 4 lb/yr 5a'.Analysis Regulatory Applicability AOCC Regulation 1 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 XVII.G.and control requirements of Reg 7,Section XVII 0.2 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 13WE2615.CP2 123/9839 One vapor recovery tower(VRT)controlled by two enclosed flares during VRU downtime.Each flare has a minimum 016 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 INatural pas venting from vapor recovery tower when the VRU is down.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=O'MW•Xx/C Ex=emissions of pollutant s 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-mol)at 60F and 1 atm Throughput(O) 0.73880307 MMscf/yr 84.33825 sct/hr MW 44.125 lb/lb-mol 0.0 02 02 4118 MMect/d mole% MW Ibxlbmol mass fraction lb/hr lb/yr Im' Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 2.04 44.01 0.899 0.020 0.20 1753.39 0.68 N2 0.11 28.013 0.031 0.001 0.01 60.29 0.03 methane 969 16.041 1.554 0.035 0.35 3029.64 1.51 ethane 21.59 30.063 6.490 0.147 1.44 12651.45 6.33 propane 38.86 44.092 17.135 0.388 3.81 33402.75 16.70 isobutane 449 58.118 2.612 0.059 0.58 5091.69 2.55 n-butane 1483 58.118 8.621 0.195 1.92 16805.54 8.40 isopentane 1.91 72.114 1.378 0.031 0.31 2685.97 1.34 n-pentane 1.78 72.114 1.284 0.029 0.29 2502.94 1.25 cyclopentane 0.55 70.13 0.389 0.009 0.09 757.63 0.38 n-Hexane 0.85 86.18 0.736 0.0167 0.16 1434.84 0.72 cydohexane 0.27 84.16 0.230 0.005 0.05 448.70 0.22 Other hexanes 1.73 86.18 1.489 0.034 0.33 2901.94 1.45 haptanes 0.46 100.21 0.463 0.010 0.10 902.49 0.45 methylcyclohexane 0.18 98.19 0.181 0.004 0.04 352.38 0.18 224-TMP 0.05 114.23 0.054 0.001 0.01 104.88 0.05 Benzene 0.18 78.12 0.139 0.0032 0.03 271.67 0.14 Toluene 0.14 92.15 0.129 0.0029 0.03 250.77 0.13 Elhylbenzene 0.01 106.17 0.011 0.0003 0.00 22.14 0.01 Xylenes 0.02 106.17 0.025 0.0006 0.01 48.64 0.02 08+Heavies 0.23 118.2492339 0.275 0.006 0.06 535.24 0.27 VOC mass frac 0.797 Total VOC(Uncontrolled) 34.26 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. 13WE2615.CP2 123/9539 One vapor recovery tower(VRT)controlled by two enclosed flares during VRU downtime.Each flare has a minimum 016 control efficiency of 95%. Flaring Information Equipment Description Flare to combust VRT gas when the VRU is down. Manufacturer Teed Model Serial Number Gas Heating Value 2459 Blu/scf Throughput 1816.716749 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress VRT gas to sales line.The VRU is considered part of the process and not included as an air pollution control device. 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 Ilia CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 99745 lb/MMscf 4637.2 lb/MMscf 34.3 tpy 1.7 tpy Gas Analysis Nox 007 lb/MMBTU 0.07 Ib/MMBTU 0.11py 0.1 ICY AP-42 CO 0.371b/MMBTU 0.37 Ib/MMBTU 0.3 tpy 0.3 tpy AP-42 Benzene 307.72 lb/MMscf 18.386 lb/MMscf 272 lb/yr 14 lb/yr Gas Analysis o-Hexane 1942.1 lb/MMscf 97.106 lb/MMscf 14351b/Yr 72 lb/yr Gas Analysis Toluene 339.42 lb/MMscf 16.971 Ib/MMscf 251 lb/yr 13 Ib/yr Gas Analysis Ethylbenzene 29.974 lb/MMscf 1.4987 lb/MMscf 22 lb/yr 1 lb/yr Gas Analysis Xylenes 65.831 lb/MMscf 3.2916 ib/MMscf 49 lb/yr 2 lb/yr Gas Analysis 224-TMP 141.96 lb/MMscf 7.0979 ib/MMscf 305 lb/yr 5 lb/yr Gas Analysis Regulatory Applicability AOCC 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.' A000 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 XVILB.2 13WE2615.CP2 123/9839 Two low-pressure separators controlled by two enclosed flares during VRU downtime.Each flare has a 017 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 !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 II,Chapter 10-Displacement Equation(104-3) Ex=O'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 101 1.404014256 MMscf/yr 160.2756 sot/hr MW 30.4049 Ib/lb-mal 0.003846614 MMscf/d mole% MW Ibx/Ibmol mass fraction Ib/hr lb/yr ay Helium 0.00 4.0026 0.000 0.000 0.00 0.00 0.00 CO2 3.05 44.01 1.342 0.044 0.57 4969.67 2.48 N2 0.19 28.013 0053 0.002 0.02 198.00 0.10 methane 41.47 16.041 6.652 0.219 2.81 24643.00 12.32 ethane 24.59 30.063 7.392 0.243 3.13 27384.54 13.69 propane 22.43 44.092 9.889 0.325 4.18 36632.55 18.32 isabutane 1.92 58.118 1.117 0.037 0.47 4137.19 2.07 n-butane 4.90 58.118 2.848 0.094 1.20 10549.46 5.27 isopentane 0.46 72.114 0.330 0.011 0.14 1221.93 0.61 n-pentane 0.50 72.114 0.364 0.012 0.15 1347.49 0.67 cyclopentane 005 70.13 0.037 0.001 0.02 136.91 0.07 n-Hexane 0.11 86.18 0.096 0.0031 0.04 354.37 0.18 cydohexane 0.04 84.16 0.036 0001 0.02 133.44 0.07 Other hexanes 0.16 86.18 0.138 0.005 0.06 512.09 0.26 hectares 0.02 100.21 0.025 0.001 0.01 92.07 0.05 methylcyclohexane 0.02 98.19 0.021 0.001 0.01 77.84 0.04 224-TMP 0.01 114.23 0.012 0.000 0.01 44.01 0.02 Benzene 0.02 78.12 0.014 0.0005 0.01 53.25 0.03 Toluene 0.01 92.15 0.011 0.0004 0.00 40.28 0.02 Ethylbenzene 0.00 106.17 0.003 00001 0.00 10.23 001 Xylenes 0.00 106.17 0.004 0.0001 0.00 15.73 0.01 C8+Heavies 0.01 222.4722626 0.022 0.0007 0.01 81.59 0.04 VOC mass frac 0.492 Total VOC(Uncontrolled) 27.72 Notes Mole%.MW,and mass fractions are based on sample of low-pressure separator gas sample collected 11/19/2014 from Pronghom P-10-15 XRLNB VRU Flowrate is based on Promax model,assuming 15%VRU downtime and applying a 20%safety factor I calculated MW for C8+ 13WE2615.CP2 123/9639 Two low-pressure separators controlled by two enclosed flares during VRU downtime.Each flare has a 017 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 1715 Btu/scf Throughput 240]884449 MMBtu/yr VRU Information-NOT APPLICABLE Equipment Description Engine to recompress low-pressure separator gas to sales line.The VRU is considered pal of the process and not included as an air pollution control devio Make Model Requested Control Efficiency Annual Bypass Time Backup f Flare Overall Control I 95.00%1 Combustion emission factor source: AP-42:Chapter 13.5 0.07 Ilb NOX/MMBlu 03] lb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission factor Uncontrolled Emissions Controlled Emissions Source VOC 39487 lb/MMscf 19]44 lb/MMscf 27.7 tpy 1.4 spy bas.Analysis Now 0.07 lb/MMBTU 0.07 lb/MMBTU 0.1 tpy 0.1 tpy AP-42 CO 0.3]lb/MMBTU 0.3]lb/MMBTU 0.4 tpy 0.4 spy AP-42 Benzene 37.926 lb/MMscf 18963 lb/MMscf 53 lb/yr 3 lb/yr Gas Analysts n-Hexane 252.40 lb/MMscf 12.620 lb/MMscf 354 lb/yr 18 lb/yr 3:,s Analysis Toluene 28.691 lb/MMscf 3.4345 lb/MMscf 40 lb/yr 2 lb/yr Gas Analysts Ethylbenzene 72834 lb/MMscf 03641 lb/MMscf 10 lb/yr 1lb/yr Gas Analysis Xylenes 11.205 lb/MMscf 05603 lb/MMscf 15 lb/yr 1lb/yr Gas Analysis 224-TMP 31.345 lb/MMscf 1.5673 Ib/MMscf 44 lb/yr 2 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" AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? Yes While the separator is existing equipment,built 5/8/2013.a new well was constructed after 8/1/2014 This separator is subject to Reg 7,Section XVILG.and control requirements of Reg 7,Section XVII.B.2 • 13WE2615.CP2 123/9039 One(1)pneumatic water transfer pump,rated at 600 scf/hr(Sandpiper, Model G1 F,Serial number 2181394).The pneumatic pump is controlled by 018 two enclosed flares.Each flare has a minimum control efficiency of 95%. Pump Information Manufactur Sandpiper Model Number:GIP Serial Pump Number:2181394 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(10.4-3) Ex=Q'MW•Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=5G 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 Q mascf/hr MW 24.02 Ib/Ib-moi Hours Of OP 9780 hoursryr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr Ib/yr tpy CO2 24753 44 0.0453 CO2 1.724 15104.163 7.552 nitrogen 0574 28 0.0067 nitrogen 0.254 2228.877 1.114 methane 6s 6756 16.04 0.4653 methane 17.693 154989.125 77.495 ethane 129315 30.07 0.1619 ethane 6.156 53926.034 26.963 propane 9.1196 44.09 0.1490 propane 5.667 49646.756 24.823 isobutane 09679 58.12 0.0210 isobutane 0.798 6994.576 3.497 n-butane 2.805 58.12 0.0679 n-butane 2.581 22608.649 11.304 isopentane 07212 72.15 0.0217 isopentane 0.824 7216.194 3.608 n-pentane 1.1646 72.15 0.0350 n-pentane 1.330 11652.773 5.826 cyclopentane 0 058 70.15 0.0017 cyclopentane 0.065 572.033 0.286 n-hexane 0.043 86.18 0.0017 n-hexane 0.065 573.672 0.287 cyclohexane 00126 84.18 0.0004 cyclohexane 0.017 147.094 0.074 Other hexanes 04374 86.18 0.0157 Other hexane. 0.597 5227.589 2.614 heptanes 0.0415 100.21 0.0017 heptanes 0.066 578.123 0.289 methylcyclohexa 00114 98.19 0.0005 methylcyclohe 0.018 155.235 0.078 224-TMP 00007 114.22 0.0000 224-TMP 0.001 11.088 0.006 Benzene 00097 78.11 0.0003 Benzene 0.012 105.074 0.053 Toluene ?0098 92.14 0.0003 Toluene 0.013 112.447 0.056 Ethylbenzene 0.0014 106.17 0.0001 Ethylbenzene 0.002 20.613 0.010 Xylenes 0.0032 106.17 0.0001.Xylenes 0.005 47.116 0.024 al.Heavies 00319 150 0.0020 C3+Heavies 0.076 663.587 0.332 Mass Fraction VOC: 0.3192 Total VOC 53.166 Heating Value I 13736TU/scf Combustion emission factor source: AP 42:Chapter 13.5 0.07 I it NOX/MMBlu 0.37 it CO/MMBb 13WE2615.CP2 123/9839 One I"i pneumatic water transfer puma 'sled at 600 scf)hr iSandolper. Model G'F.'Hera rumcer 2'8'394).Toe Pneumalm ourro s controlled oy 018 two enclosed Flares.Eacn flare has a mmlmum control eHioency of 95%. zanies Mole%.MW.and mass fractions are based on wmghted average of sales gas samples collected 7123i2013 from Pronghorn TP3HNB and 11719;201- Emissions are based on 87130 hours of operation poryear. Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 20231 tb/MMscf 1011.5 Ib/MMscf 53.2 tpy 2.7 toy Gas Analysis Nox 0 C lb/MMBTU 0.07 lb/MMBTU 0.2 tpy 0.2 tpy AP 42 CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 1.3 tpy 1.3 toy AP 42 Benzene 19991 Ib/MMscf 0.9996 Ib/MMscf 105 lb/yr 5 b/yr Gas>namsis n-Hexane 109.15 Ib/MMscf 5.4573 Ib/MMsd 574 lb/yr 29 b/yr Gas Aeaiesis Toluene 21.394 lb/MMscf 1.0697 lb/MMscf 112 lb/yr 6 lb/yr Gas All4h/SIS Ethylbenzene 392'8 Ib/MMscf 0.1961 lb/MMscf 21 lb/yr 3 lb/yr Gas Analysis Xyienes 8.9642 Ib/MMscf 0.4482 b/MMsd 47 Ib/yr 2 Ib/yr Gss Analysis 13WE2615.072 123/9839 AIRS(County/Plant)123/9839 Permit No.13WE2615 Date 5/1212015 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions reportable Point it SCC Pollutant or CAS Factor Emission Factor Source (tpy)' (4yr PTE SPY)*OP.Elf% P VOC 110714 Ibt1000 gdPromaa 1.5 29.5 95% _ Yes NOx 0.0680 lb/Mrnbtu AP-42 Table 13.5 0.1 0.1 0% blo CO 0.3700 lb/Mmblu AP-42 Table 13.5 0.4 0.4 0% No 002 40400311 Benzene 0.0183 lb/1000 ga Promax 5 98 95% No • n-Hexane 0.0988 lb/1000 qa Pmmaa 26 527 95% Yes Toluene 0.0182 lb/1000 ga Pmmaa 5 97 95% No Etbpbenzene 0001810/t 000 g.Pmmaa 1 10 95% No %penes 00042 lb/1000 garrromdx .. '- 1 22 95% No 6.238 ILV1000 ga CDPHE 0.7 14.9 95% Yes 003 40400315 Benzene 0.167 lb/1000 ga CDPHE 40 797 95% Yes n-Hexane 0.524 lb/1000 ga CDPHE 125 2505 - 95% Yes VOC 1.8759 IN1000 ga AP-42 1.7 5 66.5% Yes Benzene 0.0120 I501050gaAP-42 22 64 66.5% No 005 40600132 n-Hexane 0.1147 Ib/1000 ga AP-42 205 612 66.5% Yes Toluene 0.0083 lb/1000 ga AP-42 15 44 66.5% No Etbpbenzene 0.0010 lb/1000 ga AP-42 2 5 66.5% No XNenes - 0.0013 lb/1000 ga AP-42 2 7 66.5% No VOC 202311btMMscf Gas Analysis 2.7 53.2 95% Yes NOx _ O0681btMMbTL AP-42 02 0.2 0% No • CO 0.37 lb/MMBTL AP-42 1.3 1.3 0% Yes 006 31000299 Benzene 19.9911btMMsct Gas Analysis 5 105 95% No • n-Hexane 109.15 lb/MMscf Gas Analysis 29 574 95% Yes Toluene 21.3941b/MMsct Gas Analysis 6 112 95% No Empbenzene 3.92181b/MMSC Gas Analysis 1 21 95% No Xylenes 8.9642 ib MMso Gas Ana yss 2 47 95% No VOC 20229 lb/MMsd Gas Analysis 5.1 101.1 95% Yes NOx 0.0681bMMBTU AP-42 0.5 0.5 0% No CO 0.37 Ib/MMBTUAP-42 2.5 2.5 0% Yes _ 014 31000205 Benzene 19.9941b/MMscf Gas Analysis 10 200 95% No n-Hexane 109.151b//MMscf Gas Analysis 55 1091 95% Yes Toluene 21.3961b/MMsc1 Gas Analysis 11 214 95% No E8,Nbenzene 3.92181bAAMscf Gas Analysis 2 39 95% No __ Xpenes I 8.90421bMMsd Gds Analysis 4 90 35% No VOC fl 927451bMMscf Gas Analysts 1.7 34.3 95% Yes NOx D.068 lb/MMBTUAP-42 0.1 0.1 0% No - CO 0.37 Ib/MMBTUAP-42 0.3 0.3 0 No rile ,innnonc Benzene 367.721E/MMsct Gas Analysis 14 272 95% Yes AIRS(County/Plant)123/9539 Permit No.13W E2615 Dale 5/12./2015 Controlled Controlled Actual Requested NCRP e Uncontrolled Emission Emissions Emissions reportable Point SCC Pollutant or CAS Factor Emisison Factor Source (tpnl (tpvY PIE pow'CM.Eft ' n-Hexane 1942.1 lb/MMscf Gas Analysis 72 1435 9515 Yes Toluene 339.42 lb/MMscf Gas Analysis 13 251 95% Yes Elhylbenzene 29.974 lbiMMscf Gas Analysis 1 22 95% No Xylenes 658311b/MMsct Gas Anaysis 2 49 95% No z_ _ _. _ _._.___ —� VOC 394871b/MMscf Gas Analysis 1.4 27.7 95% Yes NOx 0068 Ib/MMBT AP-42 0.1 0.1 0% No CO 0.37 Ib/MMs AP-42 0.4 0.4 0 No 17 31000206 Benzene 37.926 Ib/MMsc/U cf Gas Analysis 3 53 95% No • n-Hexane 252.401b/MMscf Gas Analysis 18 354 95% Yes Toluene 28 691 Gas Analysis 2 40 95 No Elhylbenzene 7 biMM cf Gas Analysis 1 10 95% No Xylenes 11.205. 11b/MM c! Gas Analysis _ 1 16 95% No VOC 202311b/MMscf Gas Analysis 2.7 53.2 95% Yes NOx 0068 Ib/MMBT6 AP-42 0.2 0.2 0% No - CO 0.37 Ib/MMsTI.AP-42 1.3 1.3 0 Yes 18 31000299 Benzene 19.991 lb/MMscf Gas Analysis 5 105 95% No • n-Hexane 109.15 lb/MMsc/ Gas Analysis 29 574 95% yes Toluene 21.394 IbiMMscf Gas Analysis 5 112 95% No Elhylbenzene 3.9218 lbiMMsef Gas Analysis 1 21 95% No Xylenes 09642 Ib/MMscf Gas Analysis 2 47 95% No N o 'c m et 0 4, 0 Co > 3 c 'E c 0 t O . i 3 i.Z' Z z '4 m = 0 2 uL O oo in 0 .0 U ° t p o v G L a aTit VI V l- -'.I w u v a a ❑ ®❑ 4. T o 0 c ❑ a. V 0 W e It) Y ^ J .)° .Z �O Y N N N Z y a a° a uvo `n E > w o Wo d d � � � : c Of U C r U N v 0 ..�'. O CL °' PD E M M m Q L E' u N " L 9 Y r, “ Ole Y L re i c O O O 0 I M z E p, o �.° .". m v •g _U .° u -I 0 •°.. 'i. �L^-.`^.. 'r ? m m v 0. m y 'F Q e m .0 3 0 -5 -0„ , a n a •S _ — _ 10 0 04 • U.01 .0 a W 0 o m m o r I® vi❑® m F-� o 8 .ter u er re c6z a• =1 ,' V M 0 °' 0 0 d°, Q o m a =.0 a m I. 0 yy s � PP e? 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