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Home My WebLink About20142216.tiff STATE OF COLORADO John W.Hickenleoper,Governor Larry Wolk,MD,MSPH doe c p Executive Director and Chief Medical Officer Fe =9$ Dedicated to protecting and improving the health and environment of the people of Colorado xk:ta`. 4300 Cherry Creek Dr.S. Laboratory Services Division r " Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Weld County -Clerk to the Board 1150 O St PO 758 RECEIVED Greeley, CO 80632 JUL 2 1 2014 July 17, 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On July 23,2014,the Air Pollution Control Division will publish a public notice for DJ Resources, LLC— French Lake 3-62-6-1H, in the The Greeley Tribune. 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 date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health& Environment APCD-S S-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure blw Pvuw� CF' ' -ptimL&1 1FL?re) -7- 201 { jTl,J (Et,CH,JMM) 2014-2216 21 M STATE OF COLORADO John W.Hickenlooper,Governor — Larry Wolk,MD, MSPH woe co.coR Executive Director and Chief Medical Officer Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr.S. Laboratory Services Division •Ian* Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: DJ Resources, LLC—French Lake 3-62-6-1H—Weld County Released To: The Greeley Tribune On: July 17, 2014 Published: July 23, 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT 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: DJ Resources, LLC Facility: French Lake 3-62-6-1H Oil and natural gas exploration and production facility SWSW Section 6, Township 6 north,Range 62 west Weld County The proposed project or activity is as follows: Oil and natural 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): • permitted emissions exceed public notice threshold values in Regulation No. 3,Part B, Section III.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application,the Division's analysis,and a draft of Construction Permit 12WE2284 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 www.colorado.gov/cdphe/AirPublicNotices 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: Michael Cleary Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-B 1 Denver,Colorado 80246-1530 cdphe.commentsapcd@state.co.us A rn STATE OF COLORADO p0�� COLORADO DEPARTM l• • B • � u• N •, NME, �w AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 • •1876*18/6* CONSTRUCTION PERMIT PERMIT NO: 1 2WE2284 Issuance 1 DATE ISSUED: ISSUED TO: DJ Resources LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and Gas facility, known as the French Lake 3-62-6-1 H, located at Section 6,Township 3 north, Range 62 west, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility Equipment ID AIRS Description Point Four(4)400 BBL fixed roof condensate storage tanks. Unknown 001 Emissions from these tanks are controlled by an enclosed flare (F-1). Flare F-2 will serve as a back-up. 5-11-060-TK50, Two(2)400 BBL fixed roof Produced Water Storage Tank 5-11-060-TK57 002 Emissions from these tanks are controlled by an enclosed flare (F-1). Flare F-2 will serve as a back-up. One (1)Arrow, Model A62, Serial Number 68116004002, natural gas-fired, naturally aspirated, 4SRB reciprocating E-01 003 internal combustion engine, site rated at 68 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system. This emission unit is used for driving the pump jack. Loadout 004 Truck loadout of condensate. Associated gas emitted from the separators and heater treater. Produced Gas Pending the completion of pipeline infrastructure at this facility, 005 emissions are routed to a flare (F-1). The flare has a minimum F-1 and F-2 combustion efficiency of 95%. The flare is enclosed. Flare F-2 will serve as a back-up. Fugitive 006 Fugitive emissions from valves, flanges, connectors, and other components This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow A62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND AIRS ID: 123/9986 Page 1 of 25 Condensate Tank Version 2009-1 Colorado Department of Public Health and Environment Air Pollution Control Division CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the APCD no later than fifteen days after issuance of this permit ty submitting a Notice of Startup (NOS)form to the APCD. The Notice of Startup (NOS) form may be downloaded online at www.cdohe.state.co.us/ap/downloadforms.html. Failure to notify the APCD of startup of the permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days(180)after issuance of this permit,compliance with the conditions contained on this permit shall be demonstrated to the Division. It is the permittee'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, II.G.2). For 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i)does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii)discontinues construction fora 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, III.F.4.) 4. The following information for all permitted equipment except fugitive emissions from equipment leaks shall be provided to the Division within fifteen (15) days after issuance of permit. • 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.) 5. 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.) EMISSION LIMITATIONS AND RECORDS 6. 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: AIRS Tons per Year Facility Equipment ID Point VOC CO Emission Type NO, Unknown 001 — 0.6 --- Point AIRS ID: 123199B6 Page 2 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 5-11-060-TK50, 002 0.06 Point 5-11-060-TK57 E-01 1.85 0.03 3.71 Point Loadout 004 --- 4.2 --- Point Produced Gas 005 7.7 24.0 12.8 Point F-1 and F-2 Fugitive 006 --- 4.6 --- Fugitive See "Notes to Permit Holder#4"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. 7. Point 006:The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. 8. 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 Equipment ID AIRS Control Device Pollutants Point Controlled Unknown 001 Enclosed combustor VOC 5-11-060-TK50, 002 Enclosed combustor VOC • 5-11-060-TK57 E-01 003 Catalyst NOx& CO Produced Gas VOC 005 Enclosed combustor F-1 and F-2 PROCESS LIMITATIONS AND RECORDS 9. These sources shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4 AIRS ID: 123/99B6 Page 3 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division Process/Consumption Limits Facility Equipment ID Point Process Parameter Annual ii Unknown 001 Condensate throughput 36,500 bbl/yr 5-11-060-TK50, 9,125 5-11-060-TK57 002 Produced water throughput bbltyr E-01 003 Fuel Consumption 4.85 MMscftyr 45,625 Loadout 004 Condensate Loading bbl/yr bbl/yr Produced Gas 36.5 005 Natural gas throughput MMscf/yr F-1 and F-2 Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months'data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility,for Division review. 10. Point 002: Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained for a consecutive period of three years. 11. Point 004: Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) STATE AND/OR FEDERAL REGULATORY REQUIREMENTS 12. 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, I I I.E.) (State only enforceable) 13. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 14. Visible emissions shall not exceed twenty percent(20%)opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30%opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. &4.) 15. No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. (Reference: Regulation No. 1, Section II.A.5.) AIRS ID: 123/99B6 Page 4 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 16. POINT 001: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 17. POINT 001: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 18. POINT 001: 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. Point 001: The flare 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.1.b If a flare or other 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. The operator shall comply with all applicable requirements of Section XVII. XVII.B.2.d.(ii)All combustion devices installed before May 1, 2014, must be equipped with an operational auto-igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 20. Point 001: The storage tankp covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six(6)tons per year based on a rolling twelve-month total must operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. XVII.C.1.b.(i)(b) Control requirements of Section XVII.C.1.b. must be achieved by May 1, 2015. XVII.C.1.d. Beginning May 1, 2014, or the applicable compliance date in Section XVII.C.1.b.(i), whichever comes later, owners or operators of storage tanks constructed before May 1, 2014 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 AIRS ID: 123/99B6 Page 5 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division • 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. XVILC.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 4 device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections XII.D.2.,XVII.C.1.a, or XVII.C.1.b. must develop, certify, and implement a documented Storage Tank Emission Management System("STEM")plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices,and/or other strategies designed to meet the requirements set forth in Section XVII.C.2.a. Owners or operators must update the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods AIRS ID: 123/9966 Page 6 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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)(b) A storage tank constructed before May 1, 2014, must comply with the requirements of Sections XVII.C.2.a. and XVII.C.2.b. by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within thirty (30) days for storage tanks with uncontrolled actual VOC emissions greater than 50 tons per year. 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 Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency >6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly• January 1, 2015 XVII.C.2.b.(iii) Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult,or inaccessible to monitor,as defined in Section XVII.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies) are designed to minimize emissions from storage tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates,and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request, including: XVII.C.3..e. 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 AIRS ID: 123199B6 Page 7 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 21. POINT 001 & 006: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling 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. The operator shall comply with all applicable requirements of Section XII. 22. POINT 002, 005: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology(RACT)for the pollutants for which the area is nonattainment or attainment/maintenance.This source shall meet the requirements to apply RACT and reduce emissions by installing and operating an enclosed combustion device. (Reference: Regulation No. 3, Part B, III.D.2.a). 23. Point 004: This source is located in an ozone non-attainment or attainment-maintenance area and is subject to the Reasonably Available Control Technology(RACT)requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 24. Point 004: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. b. All compartment hatches (including thief hatches)shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 24 (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. 25. Point 004: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 26. Point 006: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to AIRS ID: 123/99B6 Page 8 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 27. Point 006: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology(RACT)for the pollutants for which the area is nonattainment or attainment/maintenance(Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection &Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a quarterly basis. ii. For each leak found in the AVO inspection, a gas detector shall be used to determine the size of the leak. The gas detector shall be regularly calibrated. Component leaks greater than 10,000 ppm shall be managed in accordance with Item (vi) below, unless it is unfeasible to make the repair without shutting down the affected operation of the facility. For such component leaks that require a shutdown to be repaired, repair shall occur during the first shutdown of the affected operation after the leak is discovered. iii. For repair,valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using portable analyzer to determine if the leak is repaired. Leak shall be considered repaired when 10,000 ppm is registered when tested. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays,and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. OPERATING & MAINTENANCE REQUIREMENTS 28. Points 001, 003&004: 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 AIRS ID: 123/9966 Page 9 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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.). 29. Point 002: a. Flares 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 flare, or by other convenient means approved by the Division,determine whether the flare is operating properly. b. If a control device is used to comply with the emission limits of this permit, the following conditions must be met: (i) Leakage of VOCs to the atmosphere must be minimized as follows: 1. Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. 2. Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. 3. Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their resolution. (ii) Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. (iii) The permittee shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. Indications of improper operation for a VCU include, but are not • limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its resolution, the date range the control was inoperable, and the produced water production through the battery during the downtime. During control device downtime, emissions shall be considered to be uncontrolled. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 30. Points 001,002&005:The owner or operator shall demonstrate compliance with Condition 14, using EPA Method 22 to measure opacity from the flare.This measurement shall consist of a minimum twenty-four consecutive readings taken at fifteen second intervals over a six minute period. (Reference: Regulation No. 1, Section II.A.1 &4) AIRS ID: 123/9966 Page 10 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 31. Point 001: The operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site- specific emissions factor using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 32. Point 005: The operator shall complete an initial site specific extended gas analysis of the natural gas produced at this site in order to verify the VOC, benzene,toluene,ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site- specific emission factors using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 33. Point 006: Within one hundred and eighty days(180)after issuance of permit,the permittee shall complete the initial extended gas analysis of gas samples and extended natural gas liquids analysis of liquids that are representative of volatile organic compound (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. The operator shall submit the results of the gas and liquids analyses and emission calculations to the Division as part of the self- certification process to ensure compliance with emissions limits. 34. Point 006: Within one hundred and eighty days(180)after commencement of operation,the operator shall complete a hard count of components at the source and establish the number of components that are operated in "heavy liquid service", "light liquid service", "water/oil service"and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. Periodic Testing Requirements 35. Point 003: This engine is 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 Opbrating Scenarios may be subject to additional testing requirements as specified in Attachment A. 36. Point 005: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the flare in order to verify the VOC content(weight fraction)of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. 37. Point 006: On an annual basis, the permittee shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. AIRS ID: 123/99B6 Page 11 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division ADDITIONAL REQUIREMENTS 38. A revised Air Pollutant Emission Notice(APEN)shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually 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(NOr) 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. 39. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 40. 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. 41. 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 AIRS ID: 123/9966 Page 12 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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. 42. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant 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 applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 43. 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. 44. 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 applicant, or the Division revokes a permit,the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 45. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 46. 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: Michael Cleary Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Issued to: DJ Resources, LLC for a facility wide AIRS ID: 123/99B6 Page 13 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division permit at a new, synthetic minor facility. AIRS ID: 123/99B6 Page 14 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder: 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 permittee 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 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 permittee 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.cdphe.state.co.us/req ulations/ai rregs/100102agcccomm onprovision sreq.pdf. 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 Point Pollutant CAS# BIN (Ib/yr) reportable? Rate (Ib/yr) Benzene 71432 A 200 No 10 001 n-Hexane 110543 C 1117 Yes 56 Benzene 71432 A 64 No 3 002 n-Hexane 110543 C 200 No 10 Formaldehyde 50000 A 139 No 1 Acetaldehyde 75070 A 18 No 18 r 003 Acrolein 107028 A 16 No 16 Benzene 71432 A 15 No 15 Toluene 108883 C 9 No 9 Benzene 71432 A 87 No 87 Toluene 108883 C 358 Yes 358 004 Xylenes 1130207 C 101 No 101 n-Hexane 110543 C 28 No 28 Benzene 71432 A 2359 Yes 118 Toluene 108883 C 1409 Yes 70 - 005 Ethylbenzene 100414 C 184 No 9 Xylenes 1130207 C 347 Yes 17 • • AIRS ID: 123/99B6 Page 15 of 25 • Colorado Department of Public Health and Environment Air Pollution Control Division n-Hexane 110543 C 12046 Yes 602 Benzene 71432 A 56 No 56 Toluene 108883 C 190 No 190 006 Ethylbenzene 100414 C 40 No 40 Xylenes 1130207 C 177 No 177 n-Hexane 110543 C 217 No 217 5) The emission levels contained in this permit are based on the following emission factors: POINT•001: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/1000gal lb/1000 gal Source Condensate Condensate Throughput Throughput VOC 15.73 _ 1.815 71432 Benzene 0.1304 4.175e-03 E&P Tanks 110543 n-Hexane 0.7286 5.200e-04 Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. POINT 002: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/1000 gal. lb/1000 gal. Source Produced Water Produced Water Throughput Throughput VOC 6.2381 3.119e-01 CDPHE PS Memo 09 71432 Benzene 0.1667 8.335e-03 CDPHE PS Memo 09 110543 n-Hexane 0.5238 2.619e-02 CDPHE PS Memo 09 Note: The controlled emissions factors for point 002 are based on the flare control efficiency of 95%. Point 003: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.9046 14.7000 0.6247 2.3520 CO 1.5406 5.8000 1.2787 4.8140 VOC 0.0106 0.0400 0.0053 0.0200 5000 Formaldehyde 0.0239 0.0900 0.0000 0.0001 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 8300 Btu/hp-hr,a site-rated horsepower value of 80, and a fuel heat value of 1200 Btu/scf. AIRS ID: 123/9986 Page 16 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division Emission Factor Sources: CAS Pollutant Uncontrolled EFSource 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); Natural Gas No Control 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); Natural Gas No Control 107028 Acrolein AP-42; Table 3.2-3 (7/2000); Natural Gas No Control 71432 Benzene AP-42; Table 3.2-3 (7/2000); Natural Gas No Control 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); Natural Gas No Control 108883 Toluene AP-42; Table 3.2-3 (7/2000); Natural Gas No Control POINT 004: Emission Factors Uncontrolled • CAS Pollutant lb/BBL Source loaded VOC 1.848 E-01 AP-42 The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) =4.5 psia M (vapor molecular weight) =68 lb/lb-mol T (temperature of liquid loaded) = 520 °R Point 005: Emission Emission CAS# Pollutant Weight% Factors Factors Source Uncontrolled Controlled Lb/MMBtu Lb/MMBtu NOx NA 0.3 NA AP-42 CO NA 0.5 NA AP-42 Emission Emission CAS # Pollutant Weight% Factors Factors Source Uncontrolled Controlled Lb/MMscf Lb/MMscf VOC 43.5 26288.6 1314.428 71432 Benzene 0.107 64.620 3.231 108883 Toulene 0.064 38.598 1.930 100414 Ethylbenzene 0.008 5.034 0 252 1330207 Xylenes 0.016 9.509 0.475 110543 n-Hexane 0.546 330.02 16.501 AIRS ID: 123/99B6 Page 17 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division Note: The controlled emissions factors for point 005 are based on the flare control efficiency of 95%. Point 006: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 311 0 185 60 Flanges 7 0 12 0 Open-ended Lines 0 0 1 2 Pump Seals 0 0 0 0 Valves 47 0 62 19 Other* 36 0 5 1 VOC Content(wt%) 39.06 -- 99.85 67.37 Benzene Content(wt%) 0.10 - 0.92 0.70 Toulene Content(wt%) 0.06 - 3.97 0.81 Ethylbenzene Content(wt%) 0.01 -- 0.86 0.06 Xylene Content(wt%) 0.01 --- 3.87 0.22 n-Hexane 0.49 -- 3.28 2.86 `Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component): Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 e Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. 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) Point 003: 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 AIRS ID: 123/9986 Page 18 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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/fr18ia08.pdf 8) Point 003: 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.gov/ttn/atw/area/arearules.htm I 9) This facility is classified as follows: Applicable Status Requirement OP Synthetic Minor Source: VOC NANSR Synthetic Minor Source MACT HH Area Source Requirements: Not Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 11) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: http://www.cdphe.state.co.us/ap/oilgaspermittinghtml AIRS ID: 123199B6 Page 19 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division AIRS ID: 123199B6 Page 20 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division ATTACHMENT A: 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. 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the AIRS ID: 123199B6 Page 21 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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. The AOS cannot be used for the permanent replacement of an entire engine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non-Attainment Area New Source Review("PSD/NANSR")unless the existing engine has emission limits that are below the significance levels in Reg 3, Part D, II.A.42. 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. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s),for circumvention of any state or federal PSD/NANSR requirement.Additionally,in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 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/CDPHE-AP/CBON/1251596520270. AIRS ID: 123/99B6 Page 22 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division 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. For comparison with a short-term limit that is either input based (lb/mmBtu), 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 Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B § II.D.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 PM10, 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 5O2: Use of natural gas as fuel PM10: 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: AIRS ID: 123199B6 Page 23 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division Rich bum 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. 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 NOx 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 bum 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, Part 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 ZZZZ AIRS ID: 123/99B6 Page 24 of 25 Colorado Department of Public Health and Environment Air Pollution Control Division A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart 777Z. An analysis of the 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 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: 123/99B6 Page 25 of 25 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: DJ Resources Permit Number: 12WE2284 Source Location: SWSW S6, T3N, R62W,Weld County (Non-Attainment) • Point 001: (4)400 BBL above ground atmospheric condensate storage tanks Point 002: (2)400 BBL above ground atmospheric produced water storage tank. Equipment Description: Point 003: Reciprocating internal combustion engine Point 004: Condensate truck loadout Point 005: Plant flare with a minimum combustion efficiency of 95%. Point 006: Fugitive emissions AIRS ID: 123-9966 Date: March 27, 2014 Review Engineer: Michael Cleary Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt *If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? Yes X No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Pt.005 was submitted on the wrong Information Request letter to the source? APEN On what date was this application complete? July 11, 2014 Section 4—Source Description AIRS Point Equipment Description Four(4) above ground 400 bbl atmospheric condensate storage tanks. Emissions 001 from these tanks are controlled by a Cimarron smokeless combustor(vapor recovery unit)with 95% control efficiency. Two (2) above ground 400 bbl atmospheric produced water storage tank. 002 Emissions from this tank are controlled by a combustor(VRU) with a minimum destruction efficiency of 95%. Page 1 One(1)Arrow, Model A62,Serial Number 6611 B004002, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine,site rated at 68 003 horsepower at 1800 RPM.This engine shall be equipped with a non-selective catalytic reduction (NSCR)system.This emission unit is used for driving the pump jack. 004 Truck loadout of condensate. 005 Separator controlled by a 25'flare stack. Flare has a minimum combustion efficiency of 95%. The flare is not enclosed. 006 Fugitive emission leaks. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes°, for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section 111.D.2) Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes"the provisions of X Yes No Regulation 7,Sections XII and XVII.C may apply) Point 002: Is this source claiming exempt status for this source based on the fraction of oil in the stored X Yes No water(less than 1%by volume crude oil on an average annual basis)? Point 002: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 002: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? If so, submit Form APCD-105 Point 004: Is this source located at an oil and gas Yes No exploration site? Point 004: If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate Yes No (hydrocarbons that have an API gravity of 40 degrees 4 or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Point 004: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes No (HAP) emissions? Point 004: Will this equipment be operated in any Yes No NAAQS nonattainment area? Point 004: Does this source load gasoline into Yes No transport vehicles Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific using E&P Tanks(Refer to Section 14 for calculations) 002 CDPHE Emission Factors (PS Memo 09-02) 003 Manufacturer data (NOx, CO and VOC)and AP-42,Table 3.2-3 for HAPS Page 2 AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P`M/T 004 L = loading losses in lb per 1000 gallons loaded S= Saturation Factor P= true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole) T=temperature of bulk liquid loaded [deg. R] 005 Site-specific using VOC weight fraction (Refer to Section 14 for calculations) 006 EPA-453/R-95-017, Table 2.4 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit (PTE) AIRS Point Process Consumption/Throughput/Production 001 43,800 BBL per year(36,500 x 1.2) 002 9,125 BBL per year 003 4.85 mmscf/yr 004 45,625 BBL per year condensate and produced water loaded 005 36.5 MMSCF/yr produced gas + 0.07 MMSCF/yr from tank vapors Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 311 0 185 60 006 Flanges 7 0 12 0 Open-Ended Lines 0 0 1 2 Pump Seals 0 0 0 0 Valves 47 0 62 19 Other 36 0 5 1 Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 36,500 BBL per year 002 9,125 BBL per year 003 4.85 mmscf/yr 004 45,625 BBL per year condensate and produced water loaded 005 36.5 MMSCF/yr Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 311 0 185 60 006 Flanges 7 0 12 0 Open-Ended Lines 0 0 1 2 Pump Seals 0 0 0 0 Valves 47 0 62 19 Other 36 0 5 1 Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Enclosed combustor 95 002 01 Enclosed combustor 95 003 01 Catalyst 84-99 Page 3 004 01 None --- 005 01 Enclosed combustor 95 006 01 None -- Point NO, VOC CO Single HAP Total 001 --- 12.1 -- 0.6 (n-hexane) 0.7 002 -- 1.2 -- 0.1 (n-hexane) 0.1 003 11.4 0.03 4.5 0.1 (formaldehyde) 0.1 PTE: 004 --- 4.2 -- -- -- 005 --- 480.0 — 6.2 (n-hexane) 7.9 006 --- 4.6 -- 0.03 (Benzene) 0.03 001 -- 12.1 --- 0.5 (n-hexane) 0.6 Uncontrolled point source 002 1.2 0.1 (n-hexane) 0.1 emission rate: 003 11.4 0.03 4.5 0.1 (formaldehyde) 0.1 004 --- 4.2 -- --- --- 005 --- 480.0 -- 6.2 (n-hexane) 7.9 006 --- 4.6 --- 0.03 (Benzene) 0.03 TOTAL(TPY) 11.4 515.0 4.5 7.0(n-hexane) 8.7' 001 --- 0.6 -- 0.03 (n-hexane) 0.03 002 --- 0.06 — — --- Controlled point source 003 1.9 --- 3.7 -- -- emission rate: 004 --- 4.2 --- --- 005 7.7 24.0 12.8 0.3 (n-hexane) 0.4 006 --- 4.6 --- 0.03 (Benzene) 0.03 TOTAL PERMITTED 9.6 31.5 16.5 0.4(n-hexane) .04 (TPY) Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled creme Controlled Emission Pollutant CAS# BIN Emission Rate emissions Rate I r (Ib/yr) reportable? • t l Point 001 Benzene 71432 A 200 No 10 n-Hexane 110543 C 1117 Yes 56 Point 002 Benzene 71432 A 64 Yes 3 n-Hexane 110543 C 200 Yes 10 Point 003 Formaldehyde 50000 A 139 No 1 Acetaldehyde 75070 A 18 No 18 Page 4 Acrolein 107028 A 16 No 16 Benzene 71432 A 15 No 15 Toluene 108883 C 9 No 9 Point 004 Benzene 71432 A 87 No NA Toluene 108883 C 358 Yes NA Xylenes 1130207 C 101 No NA n-Hexane 110543 C 28 No NA Point 005 Benzene 71432 A 2359 Yes 118 Toluene 108883 C 1409 Yes 70 Ethylbenzene 100414 C 184 No 9 Xylenes 1130207 C 347 No 17 n-Hexane 110543 C 12046 Yes 602 Point 006 Benzene 71432 A 56 Yes 56 Toluene 108883 C 190 No 190 Ethylbenzene 100414 C 40 No 40 Xylenes 1130207 C 177 No 177 n-Hexane 110543 C 217 No 217 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001 01 VOC CDPHE PS Memo 05-01 Site-specific sampling 005 01 VOC, State only requirement Site-specific gas HAPS ' analysis 005 01 VOC, Regulation No. 1, Section II.A.5 Method 9 HAPS 006 01 VOC, State only requirement Site-specific gas HAPS analysis 006 01 VOC, State only requirement Hard component HAPS count Section 9—Source Classification Is this a new previously un-permitted source? 001 002 003 004 005 006 YES X X X X X X NO Page 5 What is this point classification? True Minor X X X X X Synthetic Minor X Major What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V X PSD X NA NSR MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? VOC For Reg. 3, Part B, III.C.1.a (emissions increase> 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? NOx emissions are less than 40 TPY. AIRS Point Section 12—Regulatory Review Regulation i -Particulate.Smoke. Carbon-Monoxide and Sutfu€,Dioxide 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, 001-006 1992)) in all subsections of Section II.A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Reaufatroh 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 001-006 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. Page 6 Regulation 3-APENs, Construction Permits, Operating Permits PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for each individual emission point in an attainment area with uncontrolled actual emissions of 001-006 two tons per year or more of any individual criteria pollutant (pollutants are not summed)for which the area is nonattainment. (Applicant is required to file an APEN since emissions from production exceed 1 tons per year VOC) Part B—Construction Permit Exemptions 001-006 Applicant is required to file a permit since uncontrolled VOC emissions are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 004 The date of interest for determining whether the source is new or modified is therefore 006 November 20, 2007(the date of the 8-hour ozone NA area designation). Pt. 004: Since the tank battery from which loadout is occurring began service after the date above, this source is considered"new or modified." Operator is using 0.6 saturation factor (submerged fill), therefore, RACT requirements are satisfied. Pt. 006: The equipment for which fugitive emissions were estimated was constructed after 11/20/2007. Operator will be required to institute a LDAR program. As an E&P site, this shall be no less than the semi-annual AVO protocol. Regulation 6- New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No Applicant is not subject as the storage vessels do not meet the applicable 001 threashold. NSPS OOOO: for each storage vessel affected facility constructed, modified or reconstructed after August 23, 2011, with VOC emissions equal to or greater than 6 tpy, For each storage vessel affected facility emitting more than 6 tpy VOC, emissions must be reduced by 95.0 percent. Emissions for this point do exceed 6 tpy. Applicant is required to reduce emissions by 95%. NSPS OOOO: for each storage vessel affected facility constructed, modified or reconstructed after August 23, 2011, with VOC emissions equal to or greater than 6 tpy, 002 For each storage vessel affected facility emitting more than 6 tpy VOC, emissions must be reduced by 95.0 percent. Emissions for this point do not exceed 6 tpy, however emissions are controlled by a flare with a destruction efficiency of 95%. NSPS JJJJ: Applies to manufacturers, owners and operators of(SI)engines. Affected engines are the following: engines that commence construction after 6/12/06 and are manufactured after 7/1/07 and are greater than or equal to 500 HP or 003 manufactured after 7/1/08 and are less than 500 HP and engines modified/reconstructed after 6/12/06. This engine was manufactured after 6/12/06 (06/21/2011), therefore, this engine must meet emission levels in 40 CFR subpart JJJJ 004 None 005 None Page 7 NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities(any processing site engaged in the extraction of natural gas liquids from field gas,fractionation of mixed natural gas liquids(NGLs)or both). Is this source at a"natural gas processing plant?" No Is this source subject to NSPS KKK? No WHY? Facility not defined as a natural gas processing plant, therefore, does not meet the criteria of NSPS KKK. 006 NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS OOOO. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and sulfur dioxide(SO2)emissions from affected facilities that commence construction, modification or reconstruction after August 23, 2011. Is this source at a"natural gas processing plant?" No Is this source subject to NSPS OOOO? No WHY? Facility not defined as a natural gas processing plant, therefore, does not meet the criteria of NSPS KKK. Reoulatidn 7—Volatile Orcianktotritounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks 001 since it is located in a non-attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC.) 002 None 003 None Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 76,000 liters of 9 004 gasoline(20,000 gallons),which is loaded directly into transport vehicles. No sections apply. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. 005 None 006 Section XII.G: Facility is not a natural gas processing plant therefore,not subject to Section XII.G. Regulation 8-Hazardous Ate. ants 001 MACT EEEE: Organic Liquids Distribution • This source is not subject to MACT EEEE because it is not located at a major source of HAP. MACT HH • This source is not subject to MACT HH because it is not located at a major source of HAP. 002 None MACT 7777: applies to existing, new and reconstructed RICE greater than 500 HP at major sourcesof HAPs, new and reconstructed engines less than 500 HP at major 003 sources,and new or reconstructed engines at area sources of HAPS. This engine is considered new 4SLB at an area source of HAP emissions. Therefore, it is subject to MACT 7777. It must meet the requirements of this subpart by meeting the requirements of NSPS JJJJ. 004 MACT EEEE: Not subject because minor source of HAPs 005 None MACT HH: If facility is MAJOR source for HAP(summation of HAPS of dehydrators and fugitives),then fugitive emissions are subject to MACT HH. 006 Is this facility considered MAJOR for HAPS? No Is this source subject to MACT HH? No WHY? Facility is area source for MACT HH, therefore, only TEG dehydrators are subject to MACT HH. This facility has no TEG dehydrators, so facility not subject to MACT HH. Page 8 i Section 13—Aerometric Information Retrieval System Coding Information Process Pollutant/ Fugiti Emission Contro Point Process Emission Factor ye Factor I Description CAS# (Y/N) Source (%) 15.73 lb/1000 gal VOC No 95 01 Condensate 0.1304 lb/1000 gal Benzene No See 95 001 0.7286 lb/1000 gal n-hexane No 95 SCC 40400301 —Fixed Roof Tank, Oil field storage of crude, breathing losses 6.2381 lb/1000 gal VOC No CDPHE PS 95 throughput Memo 09-02 01 Produced Water 0.1667 lb/1000 gal Benzene No CDPHE PS 95 002 0.5238 lb/1000 gal n-Hexane No CDPHE PS 95 throughput Memo 09-02 SCC 40400315—Fixed Roof Tank, Produced Water, working+breathing+flashing losses 14.700 g/hp-hr NOx No manufacturer 84 Reciprocating 5.800 g/hp-hr CO No manufacturer 17 01 Internal 003 Combustion 0.040 g/hp-hr VOC No manufacturer so Engine 0.090 g/hp-hr Formaldehyde No manufacturer 9a9 SCC 20200253: 4-cycle Rich burn Truck lb/1000 gal 01 Condensate 4.40 throughput VOC No AP-42 0 004 Loadout SCC 4060132: Crude Oil: Submerged Loading (Normal Service) 26288.6 lb/MMscf VOC No Engineering 95 Calculation 0.3 lb/MMBtu NOx No Manufacturer NA 0.5 lb/MMBtu CO No Manufacturer NA 64.620 lb/MMscf Benzene No Engineering 95 Calculation 01 Flare Engineering 005 38.598 lb/MMscf Toluene No 95 Calculation • Engineering 5.034 lb/MMscf Ethlybenzene No Calculation 95 9.509 lb/MMscf Xylenes No Engineering 95 Calculation 330.020 lb/MMscf n-hexane No Engineering 95 Calculation SCC 31000205-Flares 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, NA 006 Emissions Table 2.4 SCC 31000220: All Equip. Leak Fugitives(Valves,flanges,connections, seals, drains) Section 14—Miscellaneous Application Notes General Page 9 APENs were submitted for a facility wide permit for a new synthetic minor, E&P site located in Weld County. This source will need to go to public comment. (aVOC emissions>25tpy) The operators process description provide, indicates two flares, one to be a back-up. The flare identified as Pt. 005 is reportedly also the flare used to control the tank emissions as the flow diagram provided would seem to support. For this reason, no O&M plan specifically referring to Pt. 005 was provided as the operator felt it would be redundant. O&M information entered in CACTIS will reflect this and it will be noted that flare(point 005) will also be covered. Section 14—Miscellaneous Application Notes AIRS Point 001 Condensate Storage Tanks Source will be permitted since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold Estimates are based on a sample taken from the French Lake dated March 13, 2012 Emissions were estimated using E&P Tanks and Vasquez Beggs with an extended natural gas liquid analysis of the oil dated 3/13/2012. The representative oil sample from this site shows a vapor pressure of 10.9 psia. Because this is less than the ambient pressure at this location, E&P Tanks modeling results in no flash emissions. To account for this,the Vasquez-Beggs Solution was used to estimate the VOC flash emissions. To estimate HAP emissions, the speciation was then based on the composition projected from the E&P Tanks output. Two of the four tanks are currently in use so the working and breathing losses were determined by modeling one tanks with 'A of the total requested throughput. The resulting values were then multiplied by two. Site-specific emission factors were back-calculated based on the resulting output estimates. Pollutant W&B (TPY) Flash (TPY) Total EF E&P Tanks Vasquez-Beggs (TPY) Lbs/bbl VOC 4.92 7.14 12.06 0.6608 Benzene 0.0526 0.0474* 0.1000 5.48 e-03 Hexane 0.2278 0.3306* 0.5584 3.06 e-02 HAP flashing estimates were derived using the ratio of each HAPNOC found in the W&b losses, applied to the total VOC flash losses calculated. This source is located in the 8-hour ozone non-attainment area (this portion of Weld County is in non- attainment). Therefore,the provisions of Regulation 7, Section XII apply to this source. The statewide requirements of Regulation 7, Section XVII.C do not currently apply to this source since actual uncontrolled emissions are less than 20 tpy. Page 10 AIRS Point 002 Produced Water Storage Tanks A permit will be issued because the facility-wide uncontrolled VOC emissions are greater than 5.0 TPY(permit threshold). Initially, the operator assumed the produced water would not flash and, therefore, estimates did not include any projected flashing losses. As we had done on a previous project, Mr. Park and I agreed that the use of state-developed factors was appropriate. I will redline the APEN accordingly. State-Developed Emission factors are: Produced Water Tank Default I County Emission Factors (lb/bbl) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 0.262 0.007 0.022 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 0.178 0.003 0.010 Remainder of Colorado 0.262 0.007 0.022 State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 This source is located in the 8-hour ozone non-attainment area AIRS Point 003 RICE A permit will be issued because the uncontrolled CO emissions are greater than 2 TPY(APEN threshold) and TOTAL FACILITY is greater than 10 TPY(permit threshold). � M Page 11 AIRS Point 004 Truck condensate loadout AP-42: Chapter 5.2 Equation 1 L= 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S= Saturation Factor P=true vapor pressure of liquid loaded [psia] M = molecular weight of vapors[lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] S 0.6 Submerged loading: dedicated normal service p 4.5 psia M 68 lb/lb-mole T 520 deg. R L 4.40 lb/10^3 gal 0.184 lb/bbl Annual requested Throughput 1916250ga1/yr Annual requested VOC emissions 84301b/yr 4.2tpy The operator has chosen to designate the emissions resulting from the loadout of both the condensate and produced water as one (1)emission point. It is assumed that the top layer of produced water will be condensate/oil and, thus, loading losses would be estimated in the same manner. Therefore, the calculations above reflect the total throughput of both loadout sources combined (54,750 bbl/yr). • Page 12 AIRS Point 003 Flare Operator provided an extended gas analysis and emissions were calculated using EPA Emission Inventory Improvement Program Publication, Volume II, Chapter 10-Displacement equation (10.4-3) where: Ex= Q * MW*Xx/C Ex= emissions of pollutant x Q =Volumetric flow rate/volume of gas processed MW= Molecular weight of gas = SG of gas " MW of air • Xx= mass fraction of x in gas C = molar volume of ideal gas (379 scf/lb-mol) at 60F and 1 atm Emissions generated from the flare are: Uncontrolled Total (lb/yr) Controlled Total (Ib/yr) NOx --- 7.69 VOC 479.766 23.998 CO --- 12.81 Benzene 2359 118 Toluene 1409 70 Ethylbenzene 184 9 Xylenes 347 17 n-hexane 12046 602 224-TMP 11 1 Emissions represent the VOC and HAP emissions as a result of the produced gas routed to the flare while the NOx and CO are estimates for combusting both the tank vapors and produced gas. VOC and HAP emission estimates have been reported separately. Emission factors were calculated to be: VOC = 479.76 x 2000 + 36.50 mmscf/yr = 26288.5520 lb/mmscf • Benzene = 2359 + 36.50 mmscf/yr = 64.6198 lb/mmscf Toluene = 1409 + 36.50 mmscf/yr = 38.5981 lb/mmscf • Ethylbenzene = 184 + 36.50 mmscf/yr = 5.0344 lb/mmscf F Xylenes = 347 - 36.50 mmscf/yr = 9.5094 lb/mmscf n-hexane = 12046 + 36.50 mmscf/yr = 330.0198 lb/mmscf 224-TMP = 11 - 36.50 mmscf/yr = 0.3009 lb/mmscf An extended gas analysis was provided in the application dated 04/13/2012. The gas analysis was perfomed less than a year of submittal. An updated extended gas analysis will not be required because: -an extended gas analysis was performed within a year of this submittal and included with this package The operators process description provided states the presence of two flares...one to be used as a back- up. The flare identified as Pt. 004 is also used to control the tank emissions as well as the separator emissions, as the flow diagram provided would seem to support. • Therefore, the flare will be subject to the more stringent, zero emissions, requirements. No O&M plan specifically referring to Pt. 004 was provided. The O&M plan submitted for the tanks will also serve for pt. 004 Page 13 AIRS Point 006 Fugitive emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). The emissions were based off of an extended gas analysis that was dated 3/13/2012. An initial extended gas analysis will not be required because the extended gas analysis provided was performed within a year of this submittal. Fugitive RACT requirements were not addressed within the original submittal. Standard E&P fugitive RACT language will be proposed. A discrepancy was noted between the component counts cited on the APEN and those on the operator's calculation sheet. The APEN was redlined to reflect those counts apparently used in the calculations. • • Page 14 Air Pollutant Emission Notice(APEN) —and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Current Status(Check all that apply) Reason for APEN Submittal (Check all that apply) AIRS ID 4#: 123/99B6/001 ❑ APEN update only° '�^- _ ❑ New or previously unreported battery ❑ Modification to existing sources ❑ Previously grandfathered battery2 ❑ Registration for coverage under general permit no.tt-id+aY ❑ Synthetic minor facility &cancellation request for individual permits: ?2 %3 • IN Located in the 8-hr Ozone Control Area3 ❑ Application for or Modification of an individualpermit 1 ❑ Registered under general permit no. GPO' N Administrative permit amendment' \ N Permitted under individual permit: 12WE2284 ❑ Other: —- - For individual permit applications,check if you want': ❑ A copy of the preliminary analysis conducted by the Division N To review a draft of the permit prior to issuance Company Name': DJ Resources-Inc-t-LC Pe, of- ib-241Y OGCC Operator#: 10213 Mailing Address10: 1600 Broadway Suite 1960 PER D. a AZ-I LE City: Denver State: CO Zip: 60526 E-mail: dbazile@djrllc.com Contact Name: Dominic Bazile Phone: 303-595-7430 Fax: rTank Battery Name": French Lake 3-62-6-1 H Number of tanks: 4 Location12(QQ Sec.Twp,Range.): SWSW S6 T3N R62W County: Weld Total tank capacity[bbl]: 1600 bbl i,I Calendar year tor which "Actual"data applies13: Projected Year(s)tank(s)were placed in service": 2012 Control Description15: MRW Technologies Flare Control Efficiency16: _95% v-_ ' Condensate Throughputs' [bbl/year] Requested": 36,500 Maximum for PTE calculation19: 361 cQO Actual20: 29,200 While Controls Operational" 29,200 I Other equipment at facility22: Produced Water Storage Tanks,Truck Loadout, Fugitives, Pump Driver Engine, Heater Treater Comments: Condensate throughputs are maximum projected. Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit E Check if the Division is to calculate emissions. N Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions18 Actual Emissions20 1 Pollutant24 [lb/bbl] PTE25 Uncontrolled Controlled' Uncontrolled26 Controlled' VOC[tons/year] 0. 660$ /2 . 0, /;-06 ra 60 J. lc '. 'j8 NOx [tons/year] -- -- -- -- -- -- CO[tons/year] -- -- -- -- -- Benzene[lbs/year] S• `12 e-o3 Ate ,z7p /0 /6p 0 £ • n-Hexane[lbs/year] 3.06 fi-°I-- //It ///7 5-6 /93 4/c Wells serviced by this tank or tank battery28 API 4: 05-123-33453 Name: French Lake 3-62-6-1 H 0 Newly Reported Well API 4: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well API 4: Name: . ❑Newly Reported Well API#: Name "1, ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ;;Ii, ❑ Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a registration for coverage under general permit GP01,I further certify that this source is and will be operated in full compliiaann e with each condition of general permit GP01. i Signature of ally uthorized Person(not a vendor or consultant) Date , Dominic Bazile Exec Vice President &COO 1 Type or Print Name of Person Signing Above Official Title Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 n n n (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South J J .7 8 re istration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 7 FL362 Form APCD-205-E&P Condensate Tank APEN.doc 1 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OII,AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Notes and Instructions See PS Memo 05-01: Condensate Tank Guidance for further information on policies,APEN requirements, definitions and emission calculations. AIRS ID#: For previously reported sources,the AIRS ID number is the 10 digit point number found in the detail section of the Division's annual emission fee invoice. For newly reported sources,leave blank so the Division may assign one. 2 Previously grandfathered:Batteries installed prior to 12/30/02 and not subsequently modified are grandfathered from minor source permitting. 3 8-hour Ozone Control Area:Adams,Arapahoe,Boulder,Broomfield,Denver,Douglas,Jefferson,and portions of Lorimer and Weld counties. 4 APEN Update Only:This notice is valid for five(5)years unless a significant change is made.A revised APEN shall be filed no less than 30 days prior to the expiration date of this APEN form. 5 Modification to existing source:Modifications include but are not limited to well additions,tank installation or replacement,repiping,etc. 6 General Permit Registration:This APEN will be considered a cancellation request for an individual permit,if general permit coverage is selected for a battery. The individual permit will not be cancelled until the general permit registration is approved. Administrative Permit Amendment: This includes company name changes,transfer of ownership,and other changes defined in Regulation No. 3, Part A,Section I.B.1. You must also submit a general Permit Application form to document the administrative amendment. S Review Draft Request: Review requests will usually add to both processing time and costs. Any additional charges incurred by the Division in providing a draft and correspondence with the applicant will be billed to the applicant The Division will consider the request an official extension of the processing deadlines specified by Regulation No. 3,Part B,Section III. 9 Company Name:The name of the owner or operator of the condensate storage tank battery. 1°Mailing Address: This is the address to which correspondence, including permits and fee invoices, will be sent. If invoices are to be sent to a different address please attach a separate page with billing address(s). 1i Tank Battery Name:A unique name for each tank battery. 12 Location:The legal STR(Section,Township,Range)location of the facility to the nearest Quarter-Quarter Section. 23 Calendar year for which "Actual" data applies: Emissions reported in this APEN will be used to calculate annual emission fees for this and all subsequent years until a revised APEN is filed. 14 Year(s)tank(s)were placed in service:The year that the battery was installed or placed in service. 25 Control Description:List any control equipment such as flares,VRUs,carbon canisters,or other capture devices,which reduce VOC emissions. 16 Control Efficiency:Enter the control efficiency(reflecting the combined destruction and capture efficiency)while controls are operational. 17 Condensate Throughput:The quantity of condensate transferred through this tank battery annually in units of barrels of condensate per year. to Requested: Requested throughput/emission levels are used for individual permitting purposes and should include a reasonable margin above actual values.Use N/A for requested throughput/emission values if the battery retains grandfathered status or if applying for GP coverage. 19 Maximum for PTE calculation:Multiply the greater of the highest rolling 12-month production total during the last five years or the projected throughput for the following 12-month period by a factor of 1.2. 20 Actual: Actual reporting levels should represent the best estimates of total annual condensate throughput and pollutant emissions for the specified data year. For the first year of operation, projected annual throughputs / emissions are acceptable. In subsequent years, actual data from the previous calendar year should be used. 22 While Controls Operational: The best estimates of actual condensate throughput while controls were installed and operational. If controls were operational for the entire calendar year, this value will be equal to the actual annual throughput. Otherwise, the throughput subjected to controls should be proportioned based on the dates the controls were operational. 22 Other equipment at facility:Enter the AIRs ID of other APEN reportable equipment at facility if assigned to a different AIRs facility ID. 23 Site-specific emission factors: Check this box if site specific emission factors are provided and used to estimate emissions. Attach supporting site-specific emission factor documentation.State EFs may be used only if uncontrolled emissions calculated with the state EFs are less than 80 tpy. - - - 24 Pollutant: Estimated annual emissions of the specified criteria and non-criteria reportable pollutants (NCRP) emitted by this tank battery and associated control equipment.If values are left blank,the Division will estimate emissions based on the reported condensate throughputs.If NCRP other than those listed are emitted above reporting thresholds,attach a completed Non-Criteria Reportable APEN Addendum listing these emissions. 25 Potential to Emit(PTEl: Estimated annual maximum potential tonnage of pollutant emitted by this tank or tank battery calculated by multiplying the "Maximum for PTE" throughput value by the appropriate emission factor. Note: This PTE value is for the battery only, the emissions from other equipment at the same stationary source should be considered when determining the PTE for the facility. 26 Uncontrolled:Estimated uncontrolled emissions from this tank battery based on the annual condensate throughput. 27 Controlled: Estimated controlled emissions from this tank battery. This value is calculated by applying the appropriate control efficiency to emissions generated from throughput"while controls operational". A control efficiency of zero should be used for emissions generated while no controls were operating. These two values are summed to obtain the annual controlled emissions. 28 Wells serviced by this tank or tank battery: List all wells from which this tank battery receives condensate. Provide the well name and API number as reported to the Colorado Oil and Gas Commission.Check if this well has not previously been reported for this tank battery. 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