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Home My WebLink About20143102.tiff A CDDPHE COLORADO CO Department of Public Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board RECEIVED 1150O St PO Box 758 OCT 0 8 2014 Greeley, CO 80632 October 7, 2014 COMMISSIONERS Dear Sir or Madam: On October 10, 2014, the Air Pollution Control Division will publish a public notice for Bonanza Creek Energy Operating Company, LLC - Latham 41-1 Production Facility, 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 i3 Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, r-. 1, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure coLo z. � . 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692-2000 www.mlorado.gov/cdphe y , .o, John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ,, .,,,,,, ` *Ian RtbI CZeineA > /0-/3-P1 0 /3-�� CC P� Wl �L j o) 2014-3102 CDPHE Public Notice Of A Proposed Project AV‘ CO '% Or Activity Warranting Public Comment Website Title: Bonanza Creek Energy Operating Company, LLC - Latham 41-1 Production Facility - Weld County Released To: The Greeley Tribune On: October 7, 2014 Published: October 10, 2014 Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Bonanza Creek Energy Operating Company, LLC Facility: Latham 41-1 Production Facility Oil and gas exploration and production facility NENE Sec 1 T4N R63W Weld County The proposed project or activity is as follows: The applicant proposes to operate an oil and gas 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 13WE1163 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Carissa Money Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us _.. . .... .. COLORADO 1 I AYOL===, STATE OF COLORADO DRAFTPHEALTH AND ENVIRONMENT �� AIR POLLUTION CONTROL DIVISION f- ` TELEPHONE: (303)692-3150 4 49,i* •1676* CONSTRUCTION PERMIT PERMIT NO: 13WE1163 Issuance 3 DATE ISSUED: ISSUED TO: Bonanza Creek Energy Operating Company LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the Lathan 41-1 Production Facility, located in the NENE Section 1, Township 4N, Range 63W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Condensate Tanks Two(2) 300 bbl and four(4)400 bbl above ground atmospheric (Latham 41- 001 condensate storage tanks controlled by one enclosed flare.The 1 & P-T-1 HZ flare has a minimum combustion efficiency of 95%. Battery) One(1)Arrow Engine Company, Model A-62, Serial Number To Be Determined, natural gas-fired, naturally aspirated, 4SRB E2 005 reciprocating internal combustion engine, site rated at 80 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR)system. This emission unit powers a pump jack. Truck 006 Truck Condensate Loadout Loadout FUG 007 Fugitive VOC equipment leaks Two(2) pneumatic water transfer pumps, each rated at 600 P-1 &P-2 008 scf/hr(Sandpiper, Model G1 F, Serial number 1981496 & 2040598).The pneumatic pumps are controlled by three enclosed flares with a minimum combustion efficiency of 95%. One (1) pneumatic water transfer pump, rated at 600 scf/hr P-3 009 (Sandpiper, Model G1 F, Serial number 4016688).The pneumatic pump is controlled by three enclosed flares with a minimum combustion efficiency of 95%. AIRS ID: 123/9AD8 Page 1 of 30 dF and Environment Pollution Control Division Facility Equipment point Description ID Sep-2, Sep- Two low-pressure separators controlled by three enclosed 3 010 flares.Each flare has a minimum combustion efficiency of 95%. One emergency flare with a minimum combustion efficiency of FL-1 011 95%. The flare is not enclosed.The emergency flare is used during periods when the pipeline is not available. Condensate • Tanks Three(3)500 bbl above ground atmospheric condensate (Latham 31- 012 storage tanks controlled by two enclosed flares.The flare has a 341 HNB minimum combustion efficiency of 95%. Battery) AIRS Point 005: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Arrow Engine Company A-62 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario(AOS), included in this permit as Attachment A. AIRS Points 008 and 009: These pumps may be replaced with another pump in accordance with the provisions of the Altemate Operating Scenario(AOS)in this permit. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. AIRS Point 011: YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ao/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section 111.G.1 and can result in the revocation of the permit 2. AIRS Point 011: The following information shall be provided to the Division within fifteen (15)days after commencement of operation. • manufacturer • model number • serial number This information shall beinduded with the Notice of Startup submitted for the equipment. (Reference: Regulation No.3,Part B, III.E.) 3. AIRS Point 011: Within one hundred and eighty days (180) after commencement of operation, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3,Part B, III.G.2). AIRS ID: 123/9AD8 Page 2 of 30 olor epa en P li ealth and Environment it Pollution Control Division 4. AIRS Points n • Y not e Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, lay submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 5. AIRS Points 001, 006-010 and 012: Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 6. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, I I I.F.4.) 7. AIRS Point 010: Within one hundred and eighty(180) days after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flowrate of natural gas vented from each low pressure separator. The operator shall use the gas flow rate listed in the application for actual flow rate until the flow meter is installed, not to exceed one hundred and eighty(180)days after issuance of this permit. 8. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 9. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 10. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Equipment ID Point NO VOC CO Emission Type x Condensate Tanks (Latham 41-1 & 001 --- 4.9 -- Point P-T-1 HZ Battery) E2 005 2.2 -- 3.7 Point AIRS ID: 123/9AD8 Page 3 of 30 tireath and Environment rRUdon'Control Division Truck LoaRA Point FUG 007 18.2 Fugitive P-1 &P-2 008 — 5.0 2.7 Point P3 008 — 2.5 1.4 Point Sep-2,Sept 010 — 13.6 4.4 Point FL-1 011 1.0 10.0 5.4 Point Condensate Tanks 012 — 1.2 — Point (Latham 3134- 1HNB Battery) See 'Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 63Y- Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including aH HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve(12)month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months'data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility,for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 11. AIRS Point 007:The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent extended gas analysis, 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. 12. 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 point Control Device Pollutants 1D Condensate Tanks (Latham 41- 001 Enclosed Flare VOC ' 1 &P-T-114Z Battery) E2 005 Non-Selective Catalytic Reduction NOx and CO P-1 &P4 008 Enclosed Rare VOC AIRS ID: 123/9AD8 Page 4 of 30 olor. 1 Depa en . P •li ealth and Environment it Pollution Control Division Cs tW: a P-3 are VOC Sep-2, Sep-3 010 Enclosed Flare VOC FL-1 011 Open Flare VOC Condensate Tanks (Latham 31- 012 Enclosed Flare VOC 34-1 HNB Battery) PROCESS LIMITATIONS AND RECORDS 13. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID Condensate Tanks (Latham 41- 001 Condensate Throughput 208,050 BBL 1 &P-T-1 HZ Battery) E2 005 Consumption of natural gas as a fuel 6.3 MMscf/yr Truck 006 Condensate Loaded 153,300 BBL loadout P-1 &P-2 008 Natural Gas Consumed 10.6 MMSCF P-3 009 Natural Gas Consumed 5.3 MMSCF Sep-2, Sep-3 010 Total Gas Vented from Both Low- 12.5 MMSCF Pressure Separators to Flares FL-1 011 Total Gas Vented from Separators to 20.8 MMSCF Emergency Flare Condensate Tanks (Latham 31- 012 Condensate Throughput 175,200 BBL 34-1HNB Battery) 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. 14. AIRS Point 010: Upon installation of the flow meter required under Condition 7, the owner or operator shall continuously monitor and record the volumetric flowrate of natural gas vented from each low pressure separator using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented from each AIRS ID: 123/9AD8 Page 5 of 30 i e a Ith and Environment r Pollution Control Division of thr oughput Th records from both low-pressure separators to demonstrate compliance with the limits specified in Condition 13 and to calculate emissions as described in this permit. STATE AND FEDERAL.REGULATORY REQUIREMENTS 15. AIRS Points 001, 005, 000, and 008 - 012: 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, IILE.)(State only enforceable) 16. 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 tebntrol 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 IlA.1.&4.) 17. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 18. 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 IIA.5.) 19. AIRS Points 001 and 012: 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. 20. AIRS Points 001 and 012: 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. 21. AIRS Points 001 and.012: The condensate storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: XVII.C.1.a. Beginning May 1, 2008, owners or operators of all atmospheric condensate storage tanks with uncontrolled actual emissions of volatile organic compounds equal to or greater than 20 tons per year based on a rolling twelve-month total shall operate air pollution control equipment that has an average control efficiency of at least 95%for VOCs on such tanks. 22. AIRS Points 001 and 012: 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, AIRS ID: 123/9AD8 Page 6 of 30 olor Depa en P li ealth and Environment it Pollution Control Division dete ' h 'ng The tor 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. 23. AIRS Points 001 and 012: The storage tanks covered by this permit are subject to Regulation 7, Section XVII.C emission control requirements. These requirements include, but are not limited to: Section XVII.C.1. Control and monitoring requirements for storage tanks XVII.C.1.b. Owners or operators of storage tanks with uncontrolled actual emissions of VOCs equal to or greater than six (6) tons per year based on a rolling twelve- month total must operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98%for hydrocarbons. XVII.C.1.b.(i)(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 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; WII.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. AIRS ID: 123/9AD8 Page 7 of 30 kh and Environment Pollution Control Division XVII.C.1.e. If is sdl icult, or inaccessible to monitor,the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XV1I.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. XVII.C.2.a. Owners or operators of storage tanks must route all hydrocarbon emissions to air pollution control equipment, and must operate without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. Compliance must be achieved in accordance with the schedule in Section XVII.C.2.b.(ii). XVII.C.2.b. Owners or operators of storage tanks subject to the control requirements of Sections Xlt.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 indude selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture,performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule In Section XVII.C.2.b.(ii)and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(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 Uncontrolled Actual VOC Monitoring Method Inspection AIRS ID: 123/9AD8 Page 8 of 30 epa en P li ealth and Environment it Pollution Control Division Dolor ency Schedule >6 and< 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 XVII.C.2.b.(iii)Owners or operators are not required to monitor storage tanks and associated equipment that are unsafe, difficult, or inaccessible to monitor, as defined in Section XVII.C.1.e. XVII.C.2.b.(iv) STEM must include a certification by the owner or operator that the selected STEM strategy(ies)are designed to minimize emissions from storage tanks and associated equipment at the facility(ies), including thief hatches and pressure relief devices. XVII.C.3. Recordkeeping XVII.C.3. The owner or operator of each storage tank subject to Sections XII.D. or XVII.C. must maintain records of STEM, if applicable, including the plan, any updates, and the certification, and make them available to the Division upon request. In addition, for a period of two (2) years, the owner or operator must maintain records of any required monitoring and make them available to the Division upon request,including: XVII.C.3.a.The AIRS ID for the storage tank. XVII.C.3.b. The date and duration of any period where the thief hatch, pressure relief device, or other access point are found to be venting hydrocarbon emissions, except for venting that is reasonably required for maintenance, gauging, or safety of personnel and equipment. XVII.C.3.c.The date and duration of any period where the air pollution control equipment is not operating. XVII.C.3.d. Where a combustion device is being used, the date and result of any EPA Method 22 test or investigation pursuant to Section XVII.C.1.d.(v). XVII.C.3.e. The timing of and efforts made to eliminate venting, restore operation of air pollution control equipment, and mitigate visible emissions. 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. 24. AIRS Point 006: 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) 25. AIRS Point 006: 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): AIRS ID: 123/9AD8 Page 9 of 30 Ith and Environment RAE I r Pollution Control Division a. Hoses • nt dripping, leaking, or other liquid or vapor loss during loading and unloading. b. NI compartment hatches(induding thief hatches)shall be dosed and latched at all times when loading operations are not active, except for periods of maintenance,gauging,or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations on site at the time of the inspection to ensure compliance with Condition 25 (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 26. AIRS Point 006: AN 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. 27. This source is subject to Regulation No. 7,y$ection XII.C General Provisions (State only enfotceable). 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 XI I. 28. AIRS Point 007: This source is subject to Regulation No. 7, Section XVII.F. leak detection and repair requirements,which include but are not limited to: XVII.F.1. As of the compliance date specified in XVII.F.4, the provisions of Section XVII.F. shall apply in lieu of any directed Inspection and maintenance program requirements established pursuant to Regulation Number 3, Part B, Section III.D.2. XVII.F.4.Requirements for well production facilities XVII.F.4.b. Owners or operators of well production facilities constructed before October 15, 2014, must identify leaks from components using an approved instrument monitoring method within ninety(90) days of the Phase-In Schedule in Table 4; within thirty (30) days for well production facilities subject to monthly approved instrument monitoring method inspections; or by January 1, 2016, for well production facilities subject to a one time approved instrument monitoring method inspection. Thereafter, approved instrument monitoring method and AVO inspections must be conducted in accordance with the Inspection Frequencies in Table 4. XVII.F.4.c. The estimated uncontrolled actual VOC emissions from the highest emitting storage tank at the well production facility determines the frequency at which inspections must be performed. Table 4—Well Production Facility Component Inspections Thresholds(per XVII.F.4.c)—Well Production Facilities Approved Instrument AVO with Storage Tanks Monitoring method Inspection Phase-In (Ipy) Inspection Frequency Frequency Schedule AIRS ID: 123/9AD8 Page 10 of 30 Depa en P li ealth and Environment it Pollution Control Division Dolor O thly January 1, 2016 > 6 and < 12 Annually Monthly January 1, 2016 > 12 and < 50 Quarterly Monthly January 1, 2015 > 50 Monthly January 1, 2015 XVII.F.5. If a component is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor the component until it becomes feasible to do so. XVII.F.6 Leaks requiring repair: Leaks must be identified utilizing the methods listed in Section XVII.F.6. Only leaks detected pursuant to Section XVII.F.6. require repair under Section XVII.F.7. XVII.F.6.a. For EPA Method 21 monitoring, or other Division approved quantitative instrument based monitoring, at facilities constructed before May 1, 2014, a leak is any concentration of hydrocarbon above 2,000 parts per million (ppm) not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation, except for well production facilities where a leak is defined as any concentration of hydrocarbon above 500 ppm not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation. XVII.F.6.c. For infra-red camera and AVO monitoring, or other Division approved non- quantitative instrument based monitoring, a leak is any detectable emissions not associated with normal equipment operation, such as pneumatic device actuation and crank case ventilation. XVII.F.6.e. For leaks identified using an approved instrument monitoring method or AVO, owners or operators have the option of either repairing the leak in accordance with the repair schedule set forth in Section XVII.F.7. or conducting follow-up monitoring using EPA Method 21 within five (5) working days of the leak detection. If the follow-up EPA Method 21 monitoring shows that the emission is a leak as defined in Section XVII.F.6.,the leak must be repaired and remonitored in accordance with Section XVII.F.7. XVII.F.7. Repair and remonitoring XVII.F.7.a. First attempt to repair a leak must be made no later than five (5) working days after discovery, unless parts are unavailable, the equipment requires shutdown to complete repair, or other good cause exists. If parts are unavailable, they must be ordered promptly and the repair must be made within fifteen (15) working days of receipt of the parts. If shutdown is required, the leak must be repaired during the next scheduled shutdown. If delay is attributable to other good cause, repairs must be completed within fifteen (15)working days after the cause of delay ceases to exist. XVII.F.7.b. Within fifteen (15) working days of completion of a repair, the leak must be remonitored to verify the repair was effective. AIRS ID: 123/9AD8 Page 11 of 30 Ith and Environment Pollution Control Division XVII.F.7.c. L of Section XVII.F.6. EfE shall not be subject to enforcement by tine Division unless the owner or operator fails to perform the required repairs in accordance with Section XVII.F.7. XVHI.F.B. Recordkeeping: The owner or operator of each facility subject to the leak detection and repair requirements in Section XVII.F.must maintain the following records for a period of two (2) years and make them available to the Division upon request. XVII.F.8.a. Documentation of the initial approved instrument monitoring method inspection for new well production facilities;, XVII.F.8.b.The date and site information for each Inspection; XVII.F.8.c. A list of the leaking components and the monitoring method(s) used to determine the presence of the leak; XVII.F.8.d. The date of first attempt to repair the leak and, if necessary, any additional attempt to repair the leak; XVII.F.8.e.The date the leak was repaired; XVII.F.B.f.The delayed repair list,including the basis for placing leaks on the list XVII.F.8.g. The date the leak was remonitored to verify the effectiveness of the repair, and the results of the remonitoring;and XVII.F.8.h. A list of components that are designated as unsafe, difficult, or inaccessible to monitor, as described in Section XVII.F.5., an explanation stating why the component is so designated,and the plan for monitoring such component(s). XVII.F.9. Reporting: The owner or operator of each facility subject to the leak detection and repair requirements in Section XVII.F..must submit reports as specified in Section XVII.F.9. 29. AIRS Point 007: 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). Upon the compliance dated specified in Regulation No. 7, Section XVII.F.4., the provisions of Section XVII.F. shall apply in lieu of RACT requirements established pursuant to Regulation Number 3, Part B, Section III.D.2. 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. AuditoryMsual/olfactory inspection (AVO) will be performed on a semi-annual basis.The first AVO inspection must be completed within 180 days of permit Issuance. ii. For each leak found in the AVO inspection, a gas detector may 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 AIRS ID: 123/9AD8 Page 12 of 30 I . olor. l •epa en P li ealth and Environment j it Pollution Control Division ty. - .° le. han 0 ppm shall not require repair. 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. Hi. 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 AVO to determine if the leak is repaired. 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 30. AIRS Points 001, 005, 008-012: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 31. AIRS Point 007: Within one hundred and eighty days (180) after issuance of this permit, 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. 32. AIRS Point 010: The operator shall complete an initial site specific extended gas analysis of the natural gas vented from each low pressure separator 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 AIRS ID: 123/9AD8 Page 13 of 30 d• : .• •: Ith and Environment Pollution Control Division be submitted • used to demonstrate compliance with the emissions factors chosen for this emissions point. 33. AIRS Point 011: Within one hundred and eighty (180) days after commencement of operation, the owner or operator shall demonstrate compliance with opacity requirements, using EPA Method 9 to measure opacity from•the flare when the flare is receiving gas from the separator.(Reference:Regulation No.1, Section I I.A.1 &4) 34. MRS Point 012: 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 thegaidance 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. Periodic Testing Requirements 35. AIRS Point 005:`This engine may be subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to.Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 36. AIRS Point 007: On an.annual basis,the owner or operator shall complete an extended gas analysis of gas samples that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas analysis shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. ALTERNATE OPERATING SCENARIOS 37. AIRS Points 008 and 009: This pump may be replaced with a likg-kind pump in accordance with the requirements of Regulation 3, Part A, Section IVA and without applying for a revision to this permit or obtaining a new construction permit. A like-kind replacement pump shall be the same make, model and capacity as authorized in this permit. 38. AIRS Points 008 and 009: The owner or operator shall maintain a log on-site or at a local field office tb contemporaneously record the start and stop dates of any pump replacement, the manufacturer, model number, serial number and capacity of the replacement pump. 39. MRS Points 008 and. 009: Alt.,pump replacements installed and operated per the alternate operating scenarios authorized by this permit must comply with all terms and conditions of this construction permit ADDITIONAL REQUIREMENTS 40. All previous versions of this permit are cancelled upon issuance of this permit. 41. This permit replaces the following permits, which are cancelled upon issuance of this permit. Existing Existing New Permit No. AIRS ID: 123/9AD8 Page 14 of 30 olor epa en P li ealth and Environment it Pollution Control Division Permit N i GP01 123/9AD8/001 13WE1163 Issuance 3 42. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN;or For volatile organic compounds (VOC) and nitrogen oxides sources (NO ) in ozone nonattainment areas emitting less than 100 tons of VOC or NO. per year, a change in annual actual emissions of one (1) ton per year or more or five percent,whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the altemative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an altemative-operating scenario and is installing a permanent replacement engine. 43. Federal regulatory program requirements(i.e. PSD, NANSR)shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). 44. MACT Subpart 777Z - National Emission Standards for Hazardous Air Pollutants for Stationary Reciprocating Internal Combustion Engines requirements shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of AIRS ID: 123/9AD8 Page 15 of 30 Ith and Environment Pollution Control Division that Subpart DRApubl in the Federal Register. (Reference:Regulation No. 8, Part E) GENERAL TERMS AND CONDITIONS 45. 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. 46. 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 257+114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 47. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction,installation and operation of the source,in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 48. 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. 49. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 50. 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. 51. 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. AIRS ID: 123/9AD8 Page 16 of 30 olor epa en P li ealth and Environment it Pollution Control Division By: Carissa Money Permit Engineer Permit History Issuance Date Description Issuance 3 This Issuance Converted AIRS ID 001 from GP01 coverage to include in this facility-wide permit. Increased throughput and emissions limits for AIRS ID 001, 006, 007, and 008. Added new points 009, 010, 011 and 012. Issuance 2 04/11/2014 Modifications to Fugitives (007) and pumps (008) Issuance 1 05/07/2013 Issued to Bonanza Creek Energy Operating Company LLC for Points 005-008. AIRS ID: 12319AD8 Page 17 of 30 ealth and Environment 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 perk are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any.specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice(APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E,Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible,but no later than noon of the next working day,followed by written notice to the Division addressing alt of the criteria set forth in Part II.E.1 of the Common Provisions Regulation. See: htto://www.colorado.aoWcs/Satellite?c=Document C&childoaaename=CDPHE- Main%2FDocument C%2FCBONAddLinkVIow5cid=12515993896418Scename=CBONWraooer 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits asindicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s)operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (Ib/yr) Benzene 71432 2,331 Yes 117 n-Hexane 110543 11,406 Yes 570 Toluene 108883 1,648 Yes 82 001 Ethylbenzene 100414 89 No 4 Xylenes 1330207 332 Yes - 17 2'2'4 540841 622 Yes 31 trimethylpentane Formaldehyde 5000 139 No 139 Methanol 67561 20 No 20 Acetaldehyde 75070 18 No 18 005 Acrolein 107028 17 No 17 Benzene 71432 10 No 10 1,3-Butadiene 106990 4 No 4 Toluene 108883 4 No 4 Benzene 71432 500 Yes 500 006 n-Hexane 110543 2,143 Yes 2,143 Toluene 108883 1,129 Yes 1,129 AIRS ID: 123/9AD8 Page 18 of 30 olor epa en P li ealth and Environment it Pollution Control Division EthylD 189 Xylenes 1330207 767 Yes 767 2'2'4 540841 323 Yes 323 trimethylpentane Benzene 71432 213 No 213 n-Hexane 110543 931 Yes 931 007 Toluene 108883 375 Yes 375 Ethylbenzene 100414 59 No 59 Xylenes 1330207 232 No 232 Benzene 71432 558 Yes 28 n-Hexane 110543 2,950 Yes 148 008 Toluene 108883 452 Yes 23 Ethylbenzene 100414 60 No 3 Xylenes 1330207 138 No 7 Benzene 71432 279 Yes 14 n-Hexane 110543 1,475 Yes 74 009 Toluene 108883 226 No 11 Ethylbenzene 100414 30 No 2 Xylenes 1330207 69 No 4 Benzene 71432 4,172 Yes 209 n-Hexane 110543 19,297 Yes 965 Toluene 108883 2,878 Yes 144 010 Ethylbenzene 100414 175 No 9 Xylenes 1330207 599 Yes 30 2.2.4 540841 1,105 Yes 55 trimethylpentane Benzene 71432 1,103 Yes 55 n-Hexane 110543 5,833 Yes 292 011 Toluene 108883 895 Yes 45 Ethylbenzene 100414 119 No 6 Xylenes 1330207 274 Yes 14 Benzene 71432 616 Yes 31 n-Hexane 110543 3,604 Yes 180 012 Toluene 108883 389 Yes 19 Ethylbenzene 100414 22 No 1 AIRS ID: 123/9AD8 Page 19 of 30 M II • • A r , and Environment FTealth lution Control Division X lk 4 2,2,4 540841 180 No 9 trimethylpentane 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors Emission Factors Uncontrolled Controlled Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42,Table 13.5 CO 0.37 lb/MMBtu 0.37 lb/MMBtu AP-42,Table 13.5 VOC 0.9363 0.0468 Promax n-Hexane 0.0548 0.0027 Promex Benzene 0.0112 0.0006 Promax Toluene 0.0079 0.0004 Promax Ethylbenzene 0.0004 0.00002 _ Promax _ Xylenes 0.0016 0.0001 Promax 2,2,4 0.003 0.0001 Promax trimethylpentane Note: The controlled emissions for this point are based on the flare control efficiency of 95%.A HHV of 2,407 BTU/scf was used for combustion calculations. Point 005: Emission Factors- Emission Factors— Uncontrolled Controlled CM Pollutant IblMMBtu glbhp-hr lb/MMBtu g/bhp-hr NOx 3.9197 14.7000 0.7466 2.8000 CO 1.5465 5.8000 1.2799 4.8000 VOC 0.0107 0.0400 0.0107 0.0400 5000 Formaldehyde 0.024 0.090 0.024 0.090 67561 Methanol 0.0031 0.0115 0.0031 0.0115 75070 Acetaldehyde 0.0028 0.0105 0.0028 0.0105 107028 Acrolein 0.0026 0.0099 0.0026 0.0099 71432 Benzene 0.0016 0.0059 0.0016 0.0059 106990 1,3-Butadiene 0.0007 0.0025 0.0007 0.0025 108883 Toluene 0.0006 0.0021 0.0006 0.0021 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8268 Btu/hp-hr, a site-rated horsepower value of 80,and a fuel heat value of 918 Btu/scf. Emission Factor Sources: CM Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Spec Sheet Manufacturer Spec Sheet CO Manufacturer Spec Sheet Manufacturer Spec Sheet VOC Manufacturer Spec Sheet No Control 5000 Formaldehyde Manufacturer Spec Sheet No Control 67561 Methanol AP-42;Table 3.2-3(7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42;Table 3.2-3(7/2000); No Control Natural Gas AIRS ID: 123/9AD8 Page 20 of 30 olor epa en P li ealth and Environment it Pollution Control Division CAS • II e Controlled EF Source 107028 Acrolein AP-42; Table 3.2-3(7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3(7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3(7/2000); No Control Natural Gas 108883 Toluene AP-42;Table 3.2-3(7/2000); No Control Natural Gas Point 006: Emission Factors- Uncontrolled Pollutant lb/BBL Source loaded VOC 0.2406 AP-42 Benzene 0.0033 AP-42 n-Hexane 0.0140 AP-42 Toluene 0.0074 AP-42 Ethylbenzene 0.0012 AP-42 Xylenes 0.0050 AP-42 2,2,4- 0.0021 AP-42 trimethylpentane The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95)using the following values: L= 12.46*S*P*M/T S=0.6(Submerged loading: dedicated normal service) P(true vapor pressure)=5.9 psia M (vapor molecular weight)=68 Ib/Ib-mol T(temperature of liquid loaded)=524 R The uncontrolled non-criteria reportable air pollutant(NCRP)emission factors were calculated by multiplying the mass fraction of each NCRP in the stable condensate by the VOC emission factor. Point 007: Component Gas Heavy Oil Light Oil Water/Oil Connectors 1715 0 839 734 Flanges 66 0 24 28 Open-ended Lines 56 0 9 2 Pump Seals 2 0 0 3 Valves 244 0 105 79 Other 117 0 11 28 VOC Content(wt. 0.3329 1 0.998 1 fraction) Benzene Content(wt. 0.0012 0 0.0136 0.0012 fraction) Toluene Content(wt 0.0011 0 0.0306 0.0003 fraction) Ethylbenzene(wt. 0.0001 0 0.0051 0.0001 fraction) AIRS ID: 123/9AD8 Page 21 of 30 en i ealth and Environment T Pollution Control Division Xylenes Content .0208 0.0001 fraction) ' n-hexane Content(wt. 0.0065 0 0.0581 0.0001 fraction) '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 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: Standard EFs-EPA-453/R-95-017 Table 2-4 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 extended gas analysis. Points 008 and 009: Emission Emission Factors- Factors- Uncontrolled Controlled Pollutant IbIMMsdvented IbIMMscfvented Source NOx 0.068 O 068 AP-42 (Ib/MMBTU) CO 0.37 0.37 AP-42 (Ib/MMBTU) VOC 19,192 959.59 Gas Analysis Benzene 53.069 2.6535 Gas Analysis n-Hexane 280.60 14.030 Gas Analysis Toluene 43.031 , 2.1516 Gas Analysis Ethylbenzene 5.7427 0.2871 Gas Analysis Xylenes 13.166 0.6583 Gas Analysis The displacement equation can found in"EPA Emission Inventory Improvement Program Publication: Volume II,Chapter 10-Displacement Equation(10.4-3)." Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,402 BTU/scf was used for calculations. Point 010: Weight Emission Emission Fraction Factors Factors Pollutant of Gas(%) Uncontrolled Controlled Source tblMMsd IblMMsd" NOx - - - 0.068 0.068 AP-42 (Ib/MMBTU) AIRS ID: 123/9AD8 Page 22 of 30 olor epF li ealth and Environment it Pollution Control Division gh ' n n Pollutant Fraction Factors Factors Source of Gas(%) Uncontrolled Controlled lb/MMscf Ib/MMscf CO(lb/MMBTU) — 0.37 0.37 AP-42 VOC 50 43,615 2,180.8 Gas Analysis Benzene 0.38 333.78 16.689 Gas Analysis Toluene 0.26 - 230.23 11.512 Gas Analysis Ethylbenzene 0.02 13.986 0.6993 Gas Analysis Xylenes 0.05 47.889 2.3944 Gas Analysis n-hexane 1.8 1,543.8 77.190 Gas Analysis 2,2,4- 0.10 88.441 4.4220 Gas Analysis trimethylpentane Note: The uncontrolled VOC and HAP emissions were calculated using Promax to estimate the VOC and HAP content of the stream and flow. The controlled VOC and HAP emissions factors for point 010 are based on a flare control efficiency of 95%. Emission factors for CO and NOx are based on AP-42 Table 13.5-1. A HHV of 1,895 BTU/scf was used for calculations. Point 011: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled lb/MMscf lb/MMscf NOx(lb/MMBTU) _- 0.068 0.068 AP-42 CO(Ib/MMBTU) — 0.37 0.37 AP-42 VOC 30 19,191 959.55 Gas Analysis Benzene 0.08 53.076 2.6538 Gas Analysis Toluene 0.07 43.036 2.1518 Gas Analysis Ethylbenzene 0.01 5.7427 0.2871 Gas Analysis Xylenes 0.02 13.166 0.6583 Gas Analysis n-hexane 0.44 280.60 14.030 Gas Analysis Note: Emission factors for CO and NOx found in AP-42 Table 13.5-1. A HHV of 1,408 BTU/scf was used for calculations. Point 012: Emission Factors Emission Factors Uncontrolled Controlled Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput NOx 0.068 lb/MMBtu 0.068 lb/MMBtu AP-42, Table 13.5 CO 0.37 lb/MMBtu 0.37 Ib/MMBtu AP-42,Table 13.5 , VOC 0.2776 0.0139 Promax n-Hexane 0.0206 0.0010 Promax Benzene 0.0035 0.0002 Promax Toluene 0.0022 0.0001 Promax Ethylbenzene 0.0001 0.00001 Promax Xylenes 0.0004 0.00002 Promax AIRS ID: 123/9AD8 Page 23 of 30 i Ith and Environment r Pollution Control Division Uncontrolled Controlled Pollutant Ib/BBL IbJBBL Source Condensate Condensate Throughput Throughput 2,2,4 0.0010 0.0001 Promax trimethylpentane Note: The controlled emissions for this point are based on the flare control efficiency of 95%. A HHV of 1,810 BTU/scf was used for calculations. - 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is veld 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)-892-3150. 7) AIRS Point 005: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary.Spark Ignition Internal Combustion Engines(See January 18, 2008 Federal Register posting—effective March 18, 2008). This rule has not yet been incorporated Into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: fritto://www.eoa.00vittn/ahvIareafirl8ia08,pg 8) AIRS Point 005: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting . effective October 19, 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing 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: htto://www.eoa.00vitinfahviricefir20au10.codf Additional information regarding area source standards can be found on the EPA website at: htto://www.eca.00v/ttnlatw/area/arearuies.html 9) This facility Is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor/Major Source of: VOC, HAPs NANSR Synthetic Minor Source of. VOC MACT ZZZZ Area Source Requirements:Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below. htto://ecfr.g0oaccess.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 1 AIRS ID: 123/9AD8 Page 24 of 30 epa en P li ealth and Environment it Pollution Control Division Part 63: NationalDolor r Poll 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 7777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 11)A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: htto://www.colorado.aov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9AD8 Page 25 of 30 DR2FfP ° t ntrol Division ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12,2012 2.Alterative 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 IVA Operational FlexibIlIty-Alternative Operating Scenarios,Regulation No.3,Pert 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. 'Permanents is defined as in the same service for more. than 90 operating days in any 12 month period.The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day,that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9AD8 Page 28 of 30 olor epa en P li ealth and Environment it Pollution Control Division 2.1.2 The owner or o I) a epl isting ressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: in some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO)emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven(7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer)as found on the Division's web site at: http://www.colorado.qov/cs/Satel I ite/CD PH E-AP/CBON/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year)or short term(lbs/unit of time)emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies)in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760),whichever applies. AIRS ID: 123/9AD8 Page 27 of 30 firth and Environment ion Control Division For comparison with a I er ' ut based (g/hp-hr) or concentration based (ppmvd g 15% 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 SO2: 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 My permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below. Rich 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 bum engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9AD8 Page 28 of 30 olor Depa en P li ealth and Environment it Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards:Section XVILE—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 burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean bum 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 7777 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ.An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9AD8 Page 29 of 30 i Ith and Environment 'r Pollution Control Division requirements for the DRAY d 'n the Applicability Reports required under Condition 2.42.Any testing required by the!ACT 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 oriaite engine has to go through the appropriate Construction/Operating permitting process prior to installation, AIRS ID: 123/9AD8 Page 30 of 30 Division Information Engineer: Carissa Money Control Engineer: NA Review Date: 08/19/2014 Application Date: 01/30/2014 Facility Identifiers Permit No. 13WE1163 AIRS County# 123. Weld Facility# 9AD8 Facility Type:exploration and production facility El Located In the 8-hour non-attainment area? O True Minor O Synthetic Minor for: r VOC F NOx rCO Administrative Information Company Name: Bonanza Creek Energy Operating Company LLC Source Name: Lathan 41-1 Production Facility Source Location: NENE Section 1,Township 4N, Range 63W SIC: 1311 Address 1: Bonanza Creek Energy Operating Company LLC Mailing Address 2: 410 17th Street,Suite 1500 Address :ity,State Zip: Denver,CO 80202 Name: Peg Young Person To Phone: 720-440-6133 Contact Fax: 720-279-2331 Email: pvoung@bonanzacrk.com 'Requested Action Self Certification Required? Yes Issuance Number: 3 Source Description: Oil and gas exploration and production facility known as the Lathan 41-1 Production Facility,located in the NENE Section 1,Township 4N,Range 63W,Weld County,Colorado. Point Name Type Control Action 001 Condensate Condensate Tanks Flare Modification-converting from GP01 to facility- Tanks wide permit Modification-increase throughput from 87600 006 Truck loadout Loadout None to 153300 bbl/yr Modification-increase emissions from 10.7 007 FUG Fugitives None tpy to 18.2 008 P-1 &P-2 Pump Flare Modification-increase emissions from 2.8 tpy to 5.6 tpy VO and 1.6 tpy Nox to 2.8 tpy 009 P-3 Pump Flare New point 010 Sep-2,Sep-3 Separator Venting Flare New point New point-this is an emergeny flare when 011 FL-1 Separator Venting Flare sales gas pipeline is not available Condensate Condensate Tanks Flare New point-new tanks associated with Latham 012 Tanks 31-34-1 HNB *Point 005 is the only other existing point covered by this facility-wide permit.No changes are being made to F 001 Two(2)300 bbl and four(4)400 bbl above ground atmospheric condensate storage tanks con I,Requsted Throughput 208050 bbl Control Flare Efficiency 95.00161 Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.9363 lb/bbl 97.4 tpy 4.9 tpy Promax Benzene 0.0112 lb/bbl 2330.7 lb/yr 116.5 lb/yr Promax n-Hexane 0.0548 lb/bbl 11406.3 lb/yr 570.3 lb/yr Promax Toluene 0.0079 lb/bbl 1647.6 lb/yr 82.4 lb/yr Promax Ethytbenze 0.0004 lb/bbl - 89.2 lb/yr 4.5 lb/yr Promax Xylenes 0,0016 lb/bbl 331.7 lb/yr 16.6 lb/yr Promax 2,2,4-IMP 0.0030 lb/bbl 621.9 lb/yr 31.1 lb/yr Promax. Nox 0.068 Ib/Mmbtu 0.07 tpy - 0.07 tpy AP-42 Table 1 CO 0.37 lb/Mmbtu 0.36 tpy 0.36 tpy AP-42 Table 1 Regulatory Review Section IIA1-Except as provided In paragraphs 2 through 6 below,no owner or operator of a source shall allow or cause the emission Into the atmosphere of any air pollutant which Is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR,Part 60, Appendix A(July,1992))in a89ubaectons of Section II.A and 0 of this regulation. Section SA5-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 shal allow or cause emissions kho 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. . _, . . .. ash .. . " r .. Section IA-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured In excess of the following limits: For. areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23184. This source is not subject because each tank is less than 19,800 gallons(471 bbl) NSPS 0000:for storage vessels in the natural gas production,transmission,and processing segments. This source Is not subject because each tank emits less than 6 tpy VOC. w.'rtsat: " XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is sullied to the emission control requirements for condensate tanks since It Is located In the nonatt inment area. XVt.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant b currently subject to Mks since actual uncontrolled emissions are greater than 20 tpy of VOC and actual uncontrolled emissions am greater than 6 tpy. 13WE1163.CP3 123/9AD8 006 Truck Condensate Loadout Calculations L=12.46*S*P*M/T(AP-42:Chapter 5.2,Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source S Saturation Factor 0.6 AP-42 P True Vapor Pressure 5.9 psia Assuming RVP 8 and AP-42 Fig 7.1-13a M Molecular Weight of Var 68 lb/lb-mole Assuming properties of gasoline RVP 7 from AP- T Liquid Temperature 523.67 deg.R EPA Tanks Met Data for Denver,CO *Source did not provide stable oil sample to document RVP.However,since assuming RVP 8 will use L 5.73 lb/10^3 gal 2.41E-01 lb/bbl Annual requested Throughput 153300 BBL/yr 6438600 gal/yr Annual requested V0C emissions 36878 lb/yr 18.44 tpy Control: None Efficiency: 0.00% NCRPs Component Mass Fraction Benzene 0.0136 n-hexane 0.0581 Toluene 0.0306 Xylenes 0.0208 Ethylbenzen 0.0051 2,2,4-TMP 0.0088 Source: Pressurized oil analysis Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 0.2406 lb/bbl 18.44 tpy 18.44 tpy AP-42 Benzene 0.0033 lb/bbl 500.25 lb/yr 500.25 lb/yr AP-42 n-Hexane 0.0140 lb/bbl 2143.11 lb/yr 2143.11 lb/yr AP-42 Toluene 0.0074 lb/bbl 1129.16 lb/yr 1129.16 lb/yr AP-42 Xylenes 0.0050 lb/bbl 767.13 lb/yr 767.13 lb/yr AP-42 Ethylbenzeni 0.0012 lb/bbl 189.04 lb/yr 189.04 lb/yr AP-43 2,2,4-TMP 0.0021 lb/bbl 322.68 lb/yr 322.68 lb/yr AP-44 Regulatory Review IReoulation 7-Volatile Organic Compounds This facility is not considered a bulk plant(in Reg.7)because it does not distribute gasoline. 13WE1163.CP3 123/9AD8 007 Fi00944PO9ntp W %tBOpts 7464.49840 Opn i%Muse 871 eieTltr Emblm Fader SCUM Marled 07 -EPA.463100.017 Table 64 Caning 161Ideney Barer Moe Cpntli s I iade Comp awM Tyre Cams �i`5 )Fate pill- P010941 .t Freno My) Table 24 Table 24 Reg.3 Cayman 1710 100604 10148 0.0% VOC - 0.3329 24000319) Fugts 66 380604 5.30606 0.0% Ware 0.0012 9.000994 Y>_ Op..-Ended lbes 50 200644 13006 0.0% Tapia 0.0011 0041/300 Pep Seale 2 4406-03 3.50644 0.0% Eiydaur 0.0001 000784.3 Vdds 244 43103 230605. 0.0% Moms 00003 0.007561 Other 117 280600 1]06-04 0.0% inisions 0.0068 0.1640190 CaaaWf 73106 730(06 0.0% VOC 1 Flange 390E-07 3.90607 0.0% Bemis Iltrvyl Opr-Ended Lire 140E-01 7.206-06 0.0% Toluene Piny 8n6 0.302400 0.30200 0.0% E32MEimne VOiss iirc-06 640606 0.0% 6)nm amr 3.20605 31005 0.0% Muni Con b. - COO- 2.106-04 7.50206 0.0% VOC - 0.096 5.114672 Flamm 24 110E-01 2.40606 00% Oman 00176 0.070441 N &W Urealid sn 9 140603 1-40E-05 0.0% Toluene y 0.0306 0.1150 Pimp lads 0 130E-04 5.10E-01 0.0% E919imr9 0.0051 0.0724172 Valve 105 2.50E-03 19064.6 0.0% Manes 0.0208 0.1077402 o1W 11 73960! 1.10E-01 0.0% nlleons 0.3861 0.8008491 Camibs 734 110f-01 100505 0.0% MC 1 4.6459127 P aps 21 190E-06 190E-06 0.0% Boor 0.0012 0.0056761 YlslilOl Opsnmtl 1100 E 2 7.50E-01 33106 0.0% Toles 0.0009 0.00130M Pump Sett 3 2.40646 2.40605 0.0% 1210791m 0.0001 0014646 Valves 79 9806.1 9.70606 0.0% MOiiws 0.011 0.0004646 Onr 28 140602 590205 0.0% }Hanna 00001 0500416 blads44 Na,—,Table PoMd2 0lmotbd Fsbtlii CaipM Ell6uut 1 q RIO 1 129909 -EM46M06017 Tea 2-4 balm, 21 11 lit-EPACNHM1)rtli 2-4 011 844919 37531bwr W-EPA115106017 TWM M 0.19 141,�T �s Ep"sswe301T TWt M 0.03 231d6WM 1 EFt.EFA453040017 Tstla 2424 0.11 930 12 -EPA488'A1017 TOM 24 0. Pquibrr M0vi8b TM 384 SI tohu11i9V Wells the sores%new or 842 Y tads lionalbar 20,4007 Its Mad the Ste's's.MA as S.9onj filmo Mamma eats 1012694443). Reg.3 O05 asn is mWial nag or reedit'Manor his agreed on Na 0iumY Ymn2 mnllbe. VOC ind MAP mvislbi laps wins nh bend m 462142 sales 0•s7 Snpla n6rY22911019 Zan Wan 41-1 W Lean PT-1-1641n Mt.Ora SYsp t one s21i1 I yard spppinl deb.no MY ✓amping wired. 130611630% 173/902 Two(2)pneumatic water transfer pumps,each rated at 600 soHhr P P . (Sandpiper,Model G1 F,Serial number 1981496&2040598).The pneumatic pumps are controlled by three enclosed flares with a minimum 008 combustion efficiency of 95%. Pump Information Manufactur Sandpiper Model Number: G1F Serial Pump Number: 1981496&2040598 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control Flare 95.00%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q'MW'Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Q 1200 scf/hr Multiplied pump capacity by 2 MW 24.3 lb/lb-mol Hours of Op. 8760 hours/yr Requested Throughput 10.512 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy CO2 2225 44 0.0403 CO2 3.100 27153.689 13.577 nitrogen 0.61 28 0.0070 nitrogen 0.541 4737.334 2.369 methane 69.79185 16.04 0.4607 methane 35.445 310495.433 155.248 ethane 13.42815 30.07 0.1662 ethane 12.785 111994.257 55.997 propane a.51125 44.09 0.1544 propane 11.882 104082.949 52.041 isobutane 0.90135 58.12 0.0216 isobutane 1.659 14529.987 7.265 n-butane 2.74565 58.12 0.0657 n-butane 5.053 44260.562 22.130 isopentane 0.4911 72.15 0.0146 isopentane. 1.122 9827.712 4.914 n-pentane 0.6009 72.15 0.0178 n-pentane 1.373 12024.989 6.012 cyclopentane 0.04525 70.15 0.0013 cyclopentane 0.101 880.425 0.440 n-hexane 0.1234 86.18 0.0044 n-hexane 0.337 2949.632 1.475 cyclohexane 0.0346 84.18 0.0012 cyclohexane 0.092 807.851 0.404 Other hexanes 0.21065 86.18 0.0075 Other hexane 0.575 5035.170 2.518 heptanes 0.1074 100.21 0.0044 heptanes 0.341 2985.118 1.493 methylcyclohexa 0.0293 98.19 0.0012 methylcyclohl 0.091 797.960 0.399 224-TMP 0O0015 114.22 0.0000 224-IMP 0.001 4.752 0.002 Benzene 0.02575 78.11 0.0008 Benzene 0.064 557.866 0.279 Toluene 0.0177 92.14 0.0007 Toluene 0.052 452.343 0.226 Ethylbenzene 0.00205 106.17 0.0001 Ethylbenzene 0.007 60.367 0.030 Xylenes 0.0047 106.17 0.0002 Xylenes 0.016 138.403 0.069 C8+Heavies 0.073 116 0.0035 C8+Heavies 0.268 2348.697 1.174 Mass Fraction VOC: 0.2993 Total VOC 100.872 13WE1163.CP3 123/9AD8 Two(2)pneumatic water transfer pumps,each rated at 800 sdmc (Sandpiper,Model G1 F,Serial number 1981496&2040598).The pneumatic pumps are controlled by twee enclosed flares wtih a minimum -008 combustion e8ldency of 95%. Heating Value I 1402 BTU/scf Careworn awrrisa tzar on AP42:chapter Its 0.07 (b NONaaBY 0.37 ( e comely We Mole%,MW,and mass fractions are based on average of sales gas analysis,samples collected 2/22/2013 from Latham 41-1 and Tat Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 19192 Ib/MMscf 959.59 lb/MMsd 100.87 tpy 5.041py Gas Malysh Nox 0.07 lb/MMBTU 0.07 lb/MMBTU 0.50 tpy 0.50 tpy AP-4% CO 0.37 Ib/MMBTU 0.37 Ib/MMBTU 2.73'tpy 2.73 tpy _ Ap- _ Benzene 53.089 Ib/MMscf .2.6535 Ib/MMscf 557.87 lb/yr 27.89 Ib/yr Gas Analysis n-Hexane 280.600 Ib/MMscf 14.030 Ib/MMscf 2949.0 l/yr 147.48 lb/yr Gas.Amlysls Toluene 43.031 Ib/MMscf 2.1516 lb/MMsd 45234 lb/1/T 22.62 lb/yr Gas Analysis %ylenes 13.1686 Ib/MMscf 0.6583 lb/MMsd 138.40 lb/yr 6.92b/yr Gas Maysif. Ethylbenzene 5.7427 Ib/MMsd 0.2871 lb/MMsd 60.37;ibyr 3.02 lb/yr Gas Analysts • r 13WE1163.CP3 123/9AD8 One(1)pneumatic water transfer pump,rated at 600 scf/hr(Sandpiper, Model G1F,Serial number 4016688).The pneumatic pump is controlled by 009 three enclosed flares with a minimum combustion efficiency of 95%. Pump Information _,_ Manufactur Sandpiper Model Number:G1F Serial Pump Number:4016688 Information Pump capacity 9.1 gallons per minute pumped natural gas 600 scf/hour used consumptio Control Flare 95.00%Efficiency Calculations EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q"MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=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 a 600 scf/hr MW 24.3 lh/Ib-mol Hours mop. 8760 hours/yr Requested Throughput 5.256 MMscf/yr Component mole% MW mass fraction Component lb/hr lb/yr tpy CO2 2225 44 0.0403 CO2 1.550 13576.844 6.788 nitrogen 0.61 28 0.0070 nitrogen 0.270 2368.667 1.184 methane 69.79185 16.04 0.4607 methane 17.722 155247.717 77.624 ethane 1342815 30.07 0.1662 ethane 6.392 55997.129 27.999 propane 6.51125 44.09 0.1544 propane 5.941 52041.474 26.021 isobutane 0.90135 58.12 0.0216 isobutane 0.829 7264.993 3.632 n-butane 2.74565 58.12 0.0657 n-butane 2.526 22130.281 11.065 isopentane 0.4911 72.15 0.0146 isopentane 0.561 4913.856 2.457 n-pentane 0.6009 72.15 0.0178 n-pentane 0.686 6012.494 3.006 cyclopentane 0.04525 70.15 0.0013 cyclopentane 0.050 440.213 0.220 n-hexane 0.1234 86.18 0.0044 n-hexane 0.168 1474.816 0.737 cyclohexane 0.0346 84.18 0.0012 cyclohexane 0.046 403.925 0.202 Other hexanes 0.21065 86.18 0.0075 Other hexane 0.287 2517.585 1.259 heptanes 0.1074 100.21 0.0044 heptanes 0.170 1492.559 0.746 methylcyclohexa 0.0293 98.19 0.0012 methylcycloht 0.046 398.980 0.199 224-7MP 0.00015 114.22 0.0000 224-TMP 0.000 2.376 0.001 Benzene 0.02575 78.11 0.0008 Benzene 0.032 278.933 0.139 Toluene 0.0177 92.14 0.0007 Toluene 0.026 226.171 0.113 Ethylbenzene 0.00205 106.17 0.0001 Ethylbenzene 0.003 30.184 0.015 Xylenes 0.0047 106.17 0.0002 Xylenes 0.008 69.202 0.035 C8+Heavies 0.073 116 0.0035 C8+Heavies 0.134 1174.348 0.587 Mass Fraction VOC: 0.2993 Total VOC 50.436 • 13WE1163.CP3 123/9AD8 One(1)pneumatic water transfer pump,rated at 600 acfmr(Sandpiper, Model G1 F,Serial number 4016688).The pneumatic pump Is controlled by 009 three enclosed flares with a minimum combustion efficiency of 95%. Heating Value I l4oz BTU/scf Combustion at friar spigot AP-42:COyYr 115 027 I D NOM A030., 0.37 I e COMM I tlals Mole%,MW,and mass fractions are based on average of sales gas analysis,samples collected 2/22/2013 from Latham 41-1 and Let Emissions Summary Table Pollutant Uncontrolled Emission Fa Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 19191.86 b/MMEd• 959.59 lb/MMscf- 50.44 tpy 2.52 tpy Gas Analysis Nox 0.07 b/MMBTU 0.07 lb/MMBTU 0.25 pry 0.25 tpy AP-42 CO 0.37 b/MMBTU 0.37 b/MMBTU 1.36 tpy 1.36 tpy AP-42 Benzene 53.07 b/MMsd 2.65 Ib/MMsd 278.93 b/yr 13.95 lb/yr Gas Analysis n-Hexane 280.60 b/MMscf 14.03 Ib/MMsd 1474.82 lb/yr 7334 lb/yr Gas Analysis Toluene. 43.03 lb/MMsd 2.15 lb/MAMsd 226.17 lb/yr 11.31 lb/yr Gas Analysis Xylenes 13.17 lb/MMscf 0.66 b/MMscf 69.20 b/yr 3.46 lb/yr Gas Analysis Ethylbenzene 5.74 lb/MR4scf . 0.29 b/MMsd 30.18 lb/yr 151 lb/yr Gas Analysis • 13WE1163.CP3 123/9.005 Two low-pressure separators controlled by three enclosed flares.Each flare has a minimum combustion efficiency of 010 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: muted to a flare !Natural gas venting from a well head separator.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Cr MW•Xx/C Ex=emissions of polulant x 0=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas'MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 sd/b-mo0 at 60F and 1 atm Throughput(01 12.50 MMec NT 1426.9 sctmr MW 33.3 gvlbnwl 0.0342456 MMscf/d mole% MW bxtllel mass fraction Ibex Mr Wv Hoban 0.00 4.0026 0.000 0.000 0.00 0.79 0.00 CO2 2.92 44.01 1.285 0.039 4.84 42371.05 21.19 1120 1.84 18 0.331 0.010 1.24 10903.23 5.45 N2 0.12 28.013 0.033 0.001 0.12 1094.19 0.55 methane 35.50 16.041 5.694 0.171 21.44 187785.98 93.89 ethane 28.45 30.063 8.554 0.257 32.20 282100.30 141.05 propane 20.62 44.092 9.090 0.273 34.22 299806.88 149.90 isobulwe 1.54 58.118 0.893 0.027 3.36 29466.83 14.73 nMtaie 4.15 58.118 2.414 0.073 9.09 79625.53 39.81 isopentane 0.56 72.114 0.402 0.012 1.52 13274.07 6.64 npenbne 0.66 72.114 0.478 0.014 1.80 15767.71 7.88 cydopnaene 0.26 70.13 0.183 0.006 0.69 6042.30 3.02 n-Hexane 0.68 86.18 0.585 0.018 2.20 19296.84 9.65 cydolexare 0.23 84.16 0.193 0.006 0.73 6375.19 3.19 Oterhexaes 1.31 86.18 1.133 0.034 4.26 37359.05 18.68 teplanes 0.49 100.21 0.489 0.015 1.84 16115.80 8.06 rllahylcyclohexane 0.17 9819 0.163 0.005 0.61 5366.62 2.68 224-TMP 0.03 114.23 0.034 0.0010 0.13 1105.48 0.55 Benzene 0.16 78.12 0.127 0.0038 0.48 4172.19 2.09 Toluene 0.09 92.15 0.087 0.0026 0.33 2877.81 1.44 EMylbanene 0.00 105.17 0.005 0.0002 0.02 174.82 0.09 • Xylenes 0.02 106.17 0.018 0.0005 0.07 598.59 0.30 08+Heavies 0.20 116 0.235 0.0071 0.88 7746.55 3.87 VOC mass sac 0.496 Total VOC(Uncontrolled) 272.59 Notes Mole%.MW,and mass fractions are based on LP separator gas predicted by Promax.Source MI need to collect initial gas sample Emissions are based on 8760 hours of operation per year. Typically I calculate the average MW of C8+based on the average MW on the analysis for the gas.This method resulted in minimal emissions increase Source used MW of 116 for CB+.Since Mere is minimal difference in emissions,I used the source's values. 13WE1163.CP3 123/9408 Two low-pressure wax*carded by It...enclosed Hare.Eadi fa Is a nimwn cwMwtlon elfancy of 010 96%. Firing bFmnSkn Equipped Dasotipbn Rue loconiuM' gas red is magi at Ns wand fact. Man4 - pd Tao L.aeod¢e�e Model and ,464.2 _ Bahl Marta 1357907.21464.21458 Gas Harm V 1805IBSsd Throughput 23666.92838IMM81u* VRU rfmnallon•NOT APPLICABLE Equipment Desnl06on .. . to ._ to Ins. Modal Mod Caid 1 .00% ^T' Fla rr1 t 7.7al ';y Combustion emission factor source: AP Ctap*19.5 0.07 lib NOXMMBM I 0.37 Ito COMMBM Embalms 8umrm,Table Pollutant UmmnUSMd Emission Factor Controlled leleem Factor Uncontrolled ErMabm controlled East= Soma VOC 43815'6MMd 21801 bdralmd 27!39 My 13.31p OaMSya Not o.07t✓MwTU • 0.07 6/aMaaww 0.81 tpy - 0.81 In ARQ CO 0.371b/FAMMU 037 N Wert 436 Wy 436 In AM2 benzene 333.78b/MWed 11[ps lis/MPAsd 4172.19 kM 20 .61 la Oaf MWy@ nlaeane 154.186/MMW 77.1906MMid anus khr 96414 kM Ow MndyS Toluene non lb/MtMcf 11312 Wad 287711 6M 143.8 kM OMMaNA Armes 47.689 b/MMd 239146MMd 398396/yr 29.986/yr Gee Analysis EUybenrsne 1316666/Mlmcf 0.696/80.bd 174116/yr 1746/14 - a Prayer 2.2,4-InnetlrybaS 56.4416/MMd 4.4220 MAW 116SA66/yr 55.176/yr smart Bayberry Appaab•_y EGIG&Btalbol The scummstdto the ally requirements krI r a In Sedan 6AS.Mo oar oropaelaofa smokeless latea other laekr the rdMrllnn of v is gases al alms or arum anasba It the alospwn of any sit paidsd Mildrb in excess of 30%opedly.' A SIMEI 2a.2 Salon LA apples to d emission sauces.'No peat,wtamw aced.NM caw a Sow the emission of odorous air mantras from any single nice same,mad In dada odors Adel ere measured In ems of the Mang Mb: Pa areas used padmilatyto rwMallala commerce pupeso 6 is a Rabat Vadzes an detected car 6r axes air has been Ma with seven(7)or more volumes of oar free ale • 13WE2163.CP3 223/9ADa One emergency flare with a minimum combustion efficiency of 95%. The flare is not enclosed.The emergency flare is 011 used during periods when the pipeline Is not available. Equipment Description This source vents natural gas from: a vet head separator%then the sales gas pipeline is not available or during emergendes Emissions from this source are: muted to a flare i Natural gas venting from a%ell head separator when the sales gas pipeline is not available or during emergendes.Emissions from this source are routed to Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Es=0•MW•)(x/C Ex=emissions of polutant x 0=Volumetric flow rateNolume 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/b+nd)at 60F and 1 atm Throughput(0) 20.78748 MMscf/yr I 2373Iscfmr MW 24.4 lbm b- d 0.056952 MMscf/d mole% MW IbMb rid mass(ration lb/hr byr WY Helium 0.01 4.0026 0.000 0.000 0.00 21.95 0.01 CO2 2225 44.01 0.979 0.040 6.13 5370&62 26.85 142 o.s1 28.013 0.171 0.007 1.07 9372.43 4.69 magma 69.79185 16.041 11.195 0.459 70.10 614043.00 307.02 ethane 13.42815 30.063 4.037 0.165 25.28 221417.09 110.71 propane 3.51125 44.092 3.753, 0.154 23.50 205833.37 102.92 isabulea 0.90135 58.118 0.524 0.021 3.28 2873206 14.37 n-butane 2.74565 58.118 1.596 0.065 9.99 8752225 43.76 isapenta s 04911 72114 0.354 0.015 2.22 19424.60 9.71 n-pentane rims 72114 0.433 0.018 2.71 23767.55 11.88 gdppedae 0.04525 70.13 0.032 0.001 0.20 1740.54 0.87 nitexane 0.1234 86.18 0.106 0.0044 0.67 5832.93 2.92 cydohexana 0.03w 84.16 0.029 0.001 0.18 1597.15 0.80 Otherhexares 021095 8&18 0.182 0.007 1.14 9957.05 4.98 heptanes 0.1074 100.21 0.108 0.004 0.67 5903.07 2.95 metMgciohexane 00293 98.19 0.029 0.001 0.18 1577.97 0.79 224-TMP am301s 114.23 0.000 0.0000 0.00 9.40 0.00 Benzene 0.02575 78.12 0.020 0.0008 0.13 1103.32 0.55 Toluene 0.0177 9215 0.016 0.0007 0.10 894.60 0.45 Etylbenzene 0.00205 106.17 0.002 0.0001 0.01 119.38 0.06 Xylenes 00047 106.17 0.005 0.0002 0.03 273.89 0.14 C8+Heavies 0.073 116 0.085 0.003 0.53 4644.55 2.32 VOC mass frac 0.296 Total VOC(ur lmaed) 199.47 Notes Mole%,MW,and mass fractions are based on average sales gas analysis,samples weeded 2/22/2013 from Latham 41-1 and Latham PT-1HZ sales Ire. Emissions are based on 8760 hours of operation per year. Typically I calculate the average MW of 08+based on the average MW on the analysis for the gas.This method resulted in slightly higher emissions Source used MW of 116 for CS..Since there is minimal difference in emissions,I used the source's values. 13WE1163.CP3 123/9808 T.R One ena0a.•YM sib minimum combustion.Rder..y of95%. The tiers r nol...S .d.The emergency tbrab 011 mod during periods ohm the Opine is not available. Equipment Osabtiar row*In Carotid 9w..S pima.I..rflreU M tide agtad fatty. Mwouba r TOO Mott TBO gar Pierre Om Naha 1400'Muted Tladdot 20298.77194 MIABluter 9w rNoertlon-NOT APPUCABLE Ead rned thecdplicn —,,.• rimes be Mee t carer 100.00% 60.00% "^T•� Rare Combustion emission Wm saw: IAr-42 ch.prr 19.5 0.07 It NOXIMwdM I 027 It C0/1411131u Emission Slmmlmy Tile rowan Uncontrolled Fmisske Facto' parboiled Engelke Fames Uncontrolled Mies connote Btadia some NO[ 1919111b/Mbled 959.55 Maid 199.471m - 109 t9F Ga Nalys Nero 0O7L/MMWU 0O7 b/br36TU. 100 by - Lm try Ay-42 CO 0376/MM61U 037 t$ 1U 531 by 5.41 toy AP-42 bmee 69.0N96/Mwad LEm6/waad. now tAr - 55.17 Mc Ga Mary* Mlarre 290.906 APAsd 14.030 bitted 593290 thy 79164 b/yr Gas Mary* Toluene 49.096 b/MMsd 2.1311 M Mrd m4A0 bA1 -- 44.73 b0.7 Gay Mary* 2711111 111e6 Matti 0.6583 tytMaf 27169 Ib/yr 13.69 b/yr Ga Analysis Ethybana ne 0.7427 b/Mwgd 0.267191/MMsd 1193e b/yr 5.97 b/yr Ga Analysis p— --,:ppBe."Npr EaS This aim is ailed t the aptly requirements for tree in Section HA 5e143 owner a aperror of.anal Ma.9re a other Ire forty contusion of sap gas Sul slower can erdnioa won the elnicepimm of sty eh poiant Mich is In excess of90%°picky: Sedion IA apples to el elision sons. Pb• person.nr.va toted,dug anaerobe 9a flan of admire sir ' co dadrmra from any mingle source such atonal in deled.br atlas which am named In.ear of the fogoverp bet: Fans used cadomimtiyfa rsidrtld amonrerdd pupses B 4.vioblai BSion as detected Mier IM odorous air hs ban Muted sat seven m a non voLmse of ode free a r.• 13'M116303 123/91011 012 Three(3)500 bbl above ground atmospheric condensate storage tanks controlled by two en Requsted Throughput 175200 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2776 lb/bbl 24.3 tpy 1.2 tpy Promax Benzene 0.0035 lb/bbl 616.1 lb/yr 30.8 lb/yr. Promax n-Hexane 0.0206 lb/bbl 3604.4 lb/yr 180.2 lb/yr Promax Toluene 0.0022 lb/bbl 389.2 lb/yr 19.5 lb/yr Promax Ethylbenze 0.0001 lb/bbl 21.9 lb/yr 1.1 lb/yr Promax Xylenes 0.0004 lb/bbl 72.9 lb/yr - 3.6 lb/yr Promax 2,2,4-TMP 0.0010 lb/bbl 180.2 lb/yr 9.0 lb/yr Promax Nox 0.068 lb/Mmbtu 0.01 tpy 0.01 tpy AP-42 Table 1 CO 0.37 lb/Mmbtu 0.08 tpy 0.08 tpy AP-42 Table 1 •Emissions are not based on site-specific sample.Will require initial sample. Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below,no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity.This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes.The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR,Part 60, Appendix A(July,1992))in all subsections of Section II.A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. ulation 2-Odor Section LA-No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air. ' -N ource Performance Sta NSPS Kb: for storage vessels greater than 19,800 gallons after 7123184. The 500 bbl tanks are above the minimum capacity threshold of-471 bbl.However,the tanks are located at the wellhead site,store condensate,and are prior to custody transfer;thus,the tanks are exempt from NSPS Kb(60.110b(d)(4)). NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject because each tank emits less than 6 tpy VOC. Motion 7-Volatile Orani Com ounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is subject to the emission control requirements for condensate tanks since it is located in the nonattainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC and actual uncontrolled emissions are greater than 6 tpy. 13WE1163.CP3 123/9AD8 0.140976 0.027413 0.168389 41-1 PT-1HZ ri= mole% Weighted average Average C02 i - :.. 2.2 0.317196 0.060308 2.24186 2.225 nitrogen .y v 0.59 0.088815 0.016173 0.623488 0.61 methane .v. ` a�'•� }, 68.3627 10.04045 1.874006 70.75569 69.79185 ethane • 13.4994 1.883002 0.370055 13.3801 13.42815 propane 8.8859 1.147065 M243587 8.258582 8.51125 isobutane ¢ 0.969 0.117532 0.026563 0.855726 0.90135 n-butane &1 3.0255 0.347619 0.082937 2.556916 2.74565 ¢t•� a�i 0.6007 0.053782 0.016467 0.417184 0.4911 • Mane , "; =' • 0.7784 0.059689 0.021338 0.481192 0.6009 1y, , _;.�• 0.0644 0.003679 0.001765 0.032335 4:04525 n-hexane , 0.1926 0.007641 0.00528 0.076731 0.1234 cydohexa j , 0.0555 0.001931 0.001521 0.020505 0.0346 . Other he r ry?�e� ' %:,:“14: 0.3197 0.014323 0.008764 0.137105 0.21065 ®y�� 0.1791 0.005033 0.00491 0.059045 0.1074 0.0486 0.00141 0.001332 0.016284 0.0293 224-TMP .; ;_ + 0.0002 1.41E-05 5.48E-06 0.000116 - 0.00015 Benzene a7 0.0402 0.001593 0.001102 0.016005 0.02575 Toluene :" �; '_-+„; 0.0297 0.000804 0.000814 0.009607 0.0177 Ethylbenz= . _;, _ 0.0036 7.05E-05 9.87E-05 0.001005 0.00205 Xylenes a r 0.0081 0.000183 0.000222 0.002407 0.0047 '`"" 0.1261 0.002805 0.003457 0.037189 0.073 • ( ,c->zz> z>> > > > > z > > ' Z > > Z 2 ! Z > > > > Z2 tn00&n0,oi0000000 0 0 0 0 ■ 00 . 000 ; ! ■ ;;;f22;G2 ° ' } ` 22 r OA 02 « E 2 ) = ; 2 ; e ! !, . , k �kk+::2E22�; ; ; ! l ; 2 ; + ; a ! ° 2 ® : = m ! ® , n•.a:,■<„e OCw- ® * 9 ® 4 $ T99! k § k ; k =_ \ LO \ \ \ \ o _; if `r . .!! x # !,!,!,!2lEtm I Ta f{ C0 g t! w&<COS))) L < < < «Cwi3ko)0C0GWoWS0CC00000 }! !!!!! ! 000000 ■ &�a &&&&&; & & , & & & & ; a = „ ! ; ! ®||§§§§§§ 00000 ■ 7 !!!I! ! IT BZ a — 8B § § | 2"OcAo§2§« 4Em § § % } k \ ( § 7 § E@ 7w° ,x0:0: ° : : , 00 — G ; © e 0 o / -! | •— \\\ a_)§e)\}r\> w & gWX \ > k c -ri / X> ZOC \ 2 /� (k8 . a C k Co\ \ , in } § § m co . Zgi = ti $ TiLWOifO = = s-Plaiinf 804ggitigliggnitilIggligiti Mini 1R +. Q� A mm �R !� g ON O f O O f� O ; 00 $ (V 1� p Wy 0 : 1'y P I R 8 g O r Y 0 l O 2 N 1 l r A N C C I I I N ^ o 6 NN pp Ili `1 hh 0 o $ mo .- n ;A . . ri ti 111) 1 1111111 1I III II a sisslilimmililia 4141111111 Hliniiiinniffi - 11HHH C C N m ♦ b i l G c �i t N 2 Y O ^i O O g N 2 ^d O O i t P I 6 . . . . . . c S 18111 8i l lL § 81 ! ih 81 ! ! q g g g a a Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY//\(C&k\\ Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) tiW j AIRS ID#': 123/9AD8/001 O APEN update only 1 4 2 <� ® Modification to existing sources \ 14azu ❑ New or previously unreported battery O Registration for coverage under general permit no.G'!1 �°'�?ao O Previously minorgran facility battery2 &cancellationrequest for individual permit': O Synthetic facility ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit O Registered under general permit no.GPOI ❑ Administrative permit amendments ❑ Permitted under individual permit: 0 Other. Application for coverage under permitkl3WE1163 I For individual permit applications,check if you wants: ®A copy of the preliminary analysis conducted by the Division 0 To review a draft of the permit prior to issuance Company Names: Bonanza Creek Energy Operating Company LLC OGCC Operator#: 8960 Mailing Address1s: 410 171°Street,Suite 1500 pyoung@BonanzaCrk.co City: Denver State: CO Zip: 80202 E-mail: m Contact Name: Peg Young Phone: 720-440-6133 Fax: 720-279-2331 Latham 41-1 Production Facility(COGCC#429651) 2-300 bbl,4-400 Tank Battery Name'I: Latham 41-1 &P-T-1HZ Tank Battery Number of tanks: bbl Location"(QQ Sec.Twp.Range.): NE/NE,Sec 1,T4N,R32W County: Weld Total tank capacity[bbl]: 2,200 Calendar year for which"Actual"data applies13: 2013 W 5 Year(s)tanks)were placed in service's: 2012 Control Descriptions: One(1)Cimarron 48"HVECD SN: 1357907 Control Efficiency's: 95% Condensate Throughput''[bbltyear] Requested": 208,050 Maximum for PTE calculation1s: 208,050 Actual�0: 69,350 While Controls Operational" 69,350 Other equipment at facility23: Heater treaters,produced water tanks,natural gas-fired engine,high/low pressure separators,pneumatic pumps. Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions". Emission Factor Battery Requested Emission's Actual Emissions2s Pollutant24 [lb/bbl] PTE25 Uncontrolled26 Controlled2s Uncontrolled" Controlled" VOC[tons/year] U i G H _oar', 97.38 97.83 4.87 32.46 1.62 NOx[tons/year] 13.31"'0,I 133.1 0. I 0.06 0.06 CO[tons/year] —8340 C.i{ .8330.0.1 0.31 0.31 Benzene[lbs/year] 0.C i 1 -0,620-1 23 314,446T4-- .J 3 t 4,140.4— i t s 209.0 781,380.1 3' .-69,9- n-Hexane[lbs/year] o,055 — II`tDUC'g - It,/CQj q . 5,7.0-1463:(- 3£51 ,757,3- /cG38g9- Wells serviced by this tank or tank batteryts (221? .i p5/3&Di'1 API#: 05-123-35856 Name: Latham 41-1 O Newly Reported Well API#: 05-123-35858 Name: Latham P-T-I HZ O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name O Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O 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 re 'station for coverage under general permit GPOI,I further certify that this source is and will be operated in full c mpliance with each conditio f permit GPOI. Signature of Legally A orized Person(not a vendor or consultant) Date David J.Lillo Vice President,Rocky Mt.Asset Management 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: 304912 filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 FormAPCD-205-E&PCondensateTankAPEN Battery 1.docx ... .. gy ... .. I I Q g g q s i C omva_g ol , p _ 1 e 9 D gp g e 4 p, WN " . it.2 Idp e o 5. ❑ ❑ ❑❑❑ W u 2`` . .MMM G a lihll 0i CO m g p . H p a 8 t r � a" � ae .. . d la �i I p a t$, ❑ ❑ . a . e ® ❑ ❑®❑ " a — a ma OO s 1 vig A t g i Zill i 1 . ,:f. 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I ut m 'v, Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CRUDE OIL STORAGE TANK BATTERY Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) / RECEIVED AIRS ID tJ': J23/9AD8/ O i"L ❑ APEN update only is � O Modification to existing sources 4IV New or _ ❑ Previoualy grmdfi�aed battery1 O Resignation for coverage tender general • . xri t. ❑ Synthetic minor facility &cancellation request for individual permit'. sett s C Apphceti0n for or Modification of an indi ' ` ® Located m the 8-hr Ozone Control Area ❑ Administrative permit amendment' ❑ Registered murder general permit no.OP0I ❑ Permitted under individual permit ® Other: ' #1 For individual permit applications,check if you want': ®A copy of the preliminary analysis conducted by the Division C To review a draft of the permit prior to issuance I Company Names: Bonanza Creek Energy Operating Company LLC MCC Operator Sr: 8960 Mailing Address1°: 41017°Street,Suite 1500 . City. Denver State: CO Zip: 80202 E-mail: m ContattNmne: Peg Young Phase: 720-440-6133 Fax: 720-279-2331 Latham 41-1 Production Facility(COGCC#429651) Tank Battery Name": Intham 31-34-1HNB Tank Battery Number of tanks: 3-500 bbl Location'r(QQ Sec.Twp.Range.): NE/NE,Sec I,T4N,R32W County: Weld Total tank capacity[bbl]: 1,500 Calendar year for which"Actual"data applies": 2013 Yeats)tank(s)were placed in service": 2013 Control Description's: Two(2)Lead 48"ECDs SN:21454,21456 Control Efficiency": 95% Condensate Throughput"[bbl/yea] Requested": 175,200 Maximum for PTE calculation19: 175,200 Actual": 58,400 While Controls Operational" 58,400 Other equipment at ficlity": Heuer treaters,produced water tanks,nasal gas-fired engine,high/low pressure separators,pneumatic pumps. Comments: Estimated emissions at thmughputs listed above. Use N/A ferregwas throng/spa/omission values unless rgaestiganLr ualpens* ❑Check if the Division is to calculate emissions. g Check if site-specific emission factors provided to calculate emission. Pollutant" Emission Factor Battery Requested Emissions" Actual Emissions" P7Ess Uncontrolled" - Controlled" Uncontrolled" Connolledz7 VOC[tons/year] 0.277 2432 2432 1.22 8.11 0.41 NOx[tons/year] 446 AD i . 1.66 O.OI 0.01 0.01 CO[tons/year] 2.5.34--04 -263*re,bfj 0.07 0.07 Benzene[lbe/year) 0-te35—ee1t3— Aw4±e,i b _ts74.06 t. .Aga a 1 -�aos -224--/D 1 n-Hexane[Ibdye r)D.oZ oft -04#34- 41-ilt0 3404 -12x5130 3664 age- let) -dn:e—' 208.6-60 kl3 Wells serviced by this tank or tank batter?' API#t 05-123-37939 Name Latham 31-34-1HNB C Newly Reported Well API#: Name: El Newly Reported Well API#: Name: O Newly Reported Well API#: Name: O Newly Reported Well API#: Name O Newly Reported Well API#: Name: O Newly Reported Well API#: . Name: O Newly Reported Well The signature below indicates that I have knowledge of the facts basin 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(P01,I further certify that this source is and will be operated in full coy ence wAh a�ph condition o permit C.T01. �lJft.l—a�'// r / - :,29 - s.O/ y Signature of Legally Person(not a vendor or consultant) Date David J.Lillo Vice President,Rocky Mt Asset Management Type or Print Name of Perks 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 API3NS. Include Air Pollution Control Division,APC D-SS-BI 304913 303)692-3150 S250 General Permit fee for each sew GP 4300(Lary Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 FormAPCD-205-E&PCondeosaeTaokAPEN Battery 2.docx Hello