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Home My WebLink About20143501.tiff i CDPHE COLORADO 17` IA CO .10 Department of Public Health b Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 11500 St PO Box 758 Greeley, CO 80632 RECEIVED November 4, 2014 NOV 0 7 2014 COMMISSIONERS Dear Sir or Madam: On November 5, 2014, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - Five Rivers K07-62-1HN, 63-1HN, 64-1HN, K-18-69HN. 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 ft Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, • t 7; Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure a.7 4300 Cherry Creek Drive S.,Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe � `o`,7. ,, John W. Hickenlooper,Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer l4 (--7,',J.,? • \'1$76,1, 11-12-144 ai: PLLPw1 > 17 WON-3501 CDPHE Public Notice Of A Proposed Project A Or Activity Warranting Public CO Comment Website Title: Noble Energy, Inc. - Five Rivers K07-62-1HN, 63-1HN, 64-1HN, K18-69HN - Weld County Notice Period Begins: November 5, 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: Noble Energy, Inc. Facility: Five Rivers K07-62-1HN, 63-1HN, 64-1HN, K18-69HN Oil and gas exploration and production facility SESE Section 8, T4N, R66W Weld County The proposed project or activity is as follows: Oil and gas exploration and production facility including condensate tanks, produced water tanks, truck loadout, three reciprocating internal combustion engines and associated fugitive emissions. 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 14WE1288 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: Stephanie Chaousy Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 1 I ®® COLORADO STATE OF COLORADO OF_COQ COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT Q� AIR POLLUTION CONTROL DIVISION x n TELEPHONE:(303)692-3150 .\ „ ./ 1896.r/ CONSTRUCTION PERMIT PERMIT NO: 14WE1288 Issuance 1 DATE ISSUED: ISSUED TO: Noble Energy, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Five Rivers K07-62-1HN, 63-1HN, 64-1 HN, K18-69HN, located in the SESE Section 8, T4N, R66W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Tank Fourteen (14) above ground 538 bbl atmospheric condensate Battery 001 storage tanks. Emissions from these tanks are controlled by an enclosed flare. PW Four (4) above ground 538 bbl atmospheric produced water 002 storage tanks. Emissions from these tanks are controlled by an enclosed flare. TLO 003 Truck loadout of condensate. Emissions from the loadout are controlled by an enclosed flare. Fugitives 004 Equipment leaks (fugitive VOCs)from a natural gas exploration and production facility. One (1) Cummins, Model G8.3, Serial Number 46851349, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP1 005 internal combustion engine, site rated at 118 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. One (1) Cummins, Model G8.3, Serial Number 46438683, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP2 006 internal combustion engine, site rated at 118 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. AIRS ID: 123/9D08 Page 1 of 24 Fugitive SM/M Version 2012-2 olo Depa en li Health and Environment it Pollution Control Division Facility AIRS Equipment Point Description ID One (1) GM, Model 5.7L, Serial Number 1M02057AH, natural gas-fired, naturally aspirated, 4SRB reciprocating internal COMP3 007 combustion engine, site rated at 88 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. Points 005 and 006: these engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another Cummins G8.3 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. Point 007: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another GM 5.7L engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at httDs://www.colorado.gov/oacific/cdphe/other-air-Dermittinq-notices. Failure to notify the Division of startup of the- permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after 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). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) AIRS ID: 123/9D08 Page 2 of 24 olor Depa en • • •Ii Health and Environment • it Pollution Control Division 4. The operator .,. pit - I r .me. '. • - -;.ting - • ;..mpling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The 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 6. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point NOx VOC CO Type Tank Battery 001 --- 13.3 --- Point PW 002 --- 2.0 --- Point TLO 003 --- 14.1 --- Point Fugitives 004 --- 49.7 --- Fugitive COMP1 005 1.1 0.8 2.3 Point COMP2 006 1.1 0.8 2.3 Point COMP3 007 2.4 0.9 4.1 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 7. 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.) AIRS ID: 123/9D08 Page 3 of 24 olo Depa en li Health and Environment it Pollution Control Division Facility Pollutants Equipment Point Control Device Controlled ID Tank Battery 001 Enclosed flare VOC and HAPS PW 002 Enclosed flare VOC and HAPS TLO 003 Enclosed flare VOC and HAPS COMP1 005 Non-selective catalytic reduction (NSCR)system NOx, CO and air-fuel ratio control COMP2 006 Non-selective catalytic reduction (NSCR)system NOx, Co and air-fuel ratio control COMP3 007 Non-selective catalytic reduction (NSCR) system NOx, CO and air-fuel ratio control 8. Point 004: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent 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. PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate 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 AIRS Process Parameter Annual Limit Point 001 Condensate throughput 500,000 BBL 002 Produced water throughput 250,000 BBL 003 Condensate Loading 500,000 BBL 005 Consumption of natural gas as a fuel 7.19 MMscf/yr 006 Consumption of natural gas as a fuel 7.19 MMscf/yr 007 Consumption of natural gas as a fuel 5.84 MMscf/yr The owner or operator shall calculate monthly process rates based on the calendar month. - 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. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. 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 AIRS ID: 123/9D08 Page 4 of 24 olor Depa en Ii Health and it Pollution ControlEnvironment Division equipment vi - si h x opaci more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. &4.) 11. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. Point 001: The flare covered by this permit is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). If a combustion device is used to control emissions of volatile organic compounds to comply with Section XII.D, it shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed combustion device, or by other means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XII. 13. Point 001: This source is subject to the recordkeeping, monitoring, reporting and emission control requirements of Regulation 7, Section XII. The operator shall comply with all applicable requirements of Section XII. 14. Point 001: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. 15. Point 001: 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. 16. Points 001 and 002: The flare covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: XVII.B.1.b If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. XVII.B.2.d.(ii) All combustion devices installed before May 1, 2014, must be equipped with an operational auto-igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. AIRS ID: 123/9D08 Page 5 of 24 D olo Depa en li Health and Environment it Pollution Control Division 17. Points 001 red is 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; XVII.C.1.d.(iii) If a combustion device is used, visual inspection of the auto-igniter and valves for piping of gas to the pilot light to ensure they are functioning properly; XVII.C.1.d.(iv) Visual inspection of the air pollution control equipment to ensure that the valves for the piping from the storage tank to the air pollution control equipment are open; and XVII.C.1.d.(v) If a combustion device is used, inspection of the device for the presence or absence of smoke. If smoke is observed, either the equipment must be immediately shut-in to investigate the potential cause for smoke and perform repairs, as necessary, or EPA Method 22 must be conducted to determine whether visible emissions are present for a period of at least one (1) minute in fifteen (15) minutes. XVII.C.1.e. If storage tanks or associated equipment is unsafe, difficult, or inaccessible to monitor, the owner or operator is not required to monitor such equipment until it becomes feasible to do so. XVII.C.2. Capture and monitoring requirements for storage tanks that are fitted with air pollution control equipment as required by Sections XII.D. or XVII.C.1. AIRS ID: 123/9D08 Page 6 of 24 0104 Depa en . • .di Health and Environment it Pollution Control Division XVII.C.2.a. O o. : - •r- . - •ra.:- i • •- :;a ust re- . -II 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 XILD.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 I the STEM plan as necessary to achieve or maintain compliance. Owners or operators are not required to develop and implement STEM for storage tanks containing only stabilized liquids. The minimum elements of STEM are listed below. XVII.C.2.b.(i) STEM must include selected control technologies, monitoring practices, operational practices, and/or other strategies; procedures for evaluating ongoing storage tank emission capture performance; and monitoring in accordance with approved instrument monitoring methods following the applicable schedule in Section XVII.C.2.b.(ii) and Inspection Frequency in Table 1. XVII.C.2.b.(ii) Owners or operators must achieve the requirements of Sections XVII.C.2.a. and XVII.C.2.b. and begin implementing the required approved instrument monitoring method in accordance with the following schedule: XVII.C.2.b.(ii)(b) A storage tank constructed before May 1, 2014, must comply with the requirements of Sections XVII.C.2.a. and XVII.C.2.b. by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within thirty (30) days for storage tanks with uncontrolled actual VOC emissions greater than 50 tons per year. XVII.C.2.b.(ii)(d) Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 — Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Schedule Uncontrolled Actual VOC Monitoring Method Emissions (tpy) Inspection Frequency > 6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 AIRS ID: 123/9D08 Page 7 of 24 olor RPF !Heafth and 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. 18. Point 003: 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) 19. Point 003: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. AIRS ID: 123/9D08 Page 8 of 24 olor Depa en • - •li Health and Environment it Pollution Control Division b. All co _ ' . t - sine . • ,- ches) - -,I be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 19 (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. 20. Point 003: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 21. Point 004: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 22. Point 004: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, III.D.2.a). This requirement to apply RACT shall be satisfied by installing/implementing the following emission controls: a. Directed Inspection & Maintenance as described below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a quarterly basis. H. 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 facility. Component leaks less than 10,000 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. AIRS ID: 123/9D08 Page 9 of 24 olor Depa en li Health and Environment it Pollution Control Division • s ctio as 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. 23. Points 005, 006 and 007: This equipment is subject to the control requirements for natural gas-fired reciprocating internal combustion engines under Regulation No. 7, Section XVII.E (State only enforceable). The owner or operator of any natural gas-fired reciprocating internal combustion 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: Maximum' Engine Construction or Emission Standard in g/hp-hr HP Relocation Date NOx CO VOC <100HP Any N/A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. OPERATING & MAINTENANCE REQUIREMENTS 24. 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 25. Points 001 and 002: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.AII) 26. Point 004: 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", AIRS ID: 123/9D08 Page 10 of 24 olor Depa en li Health and Environment it Pollution Control Division "water/oil se s tors ubmit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 27. Points 005, 006 and 007: A source initial compliance test shall be conducted on emissions points 005, 006 and 007 to measure the emission rate(s) for the pollutants listed below in order to demonstrate compliance with the emission limits in this permit. The test protocol must be in accordance with the requirements of the Air Pollution Control Division Compliance Test Manual and shall be submitted to the Division for review and approval at least thirty (30) days prior to testing. No compliance test shall be conducted without prior approval from the Division. Any compliance test conducted to show compliance with a monthly or annual emission limitation shall have the results projected up to the monthly or annual averaging time by multiplying the test results by the allowable number of operating hours for that averaging time (Reference: Regulation No. 3, Part B., Section III.G.3) Oxides of Nitrogen using EPA approved methods. Carbon Monoxide using EPA approved methods. Periodic Testing Requirements 28. Point 004: 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. 29. Points 005, 006 and 007: These engines are 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. ADDITIONAL REQUIREMENTS 30. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30'" 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 AIRS ID: 12319D08 Page 11 of 24 olo Depa en li E it PollutionHealthand Control Divisionnvironment For a • 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. 31. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS 32. This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in 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. 33. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. 34. This permit is issued in reliance upon the accuracy and completeness of information supplied by the owner or operator and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the owner or operator or owner or operator's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 35. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 36. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division APCD grounds set forth in the Colorado Air Quality (APCD) on AIRS ID: 12319D08 Page 12 of 24 olor. Depa en .Ii Health and Environment it Pollution Control Division Control Act a= : ati. • ' Q -< trol ission (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. 37. Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. If a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate. 38. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By. Stephanie Chaousy, PE Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. Newly permitted condensate tanks, produced water tanks, truck loadout, three reciprocating internal combustion engines and associated fugitives at a synthetic minor facility. AIRS ID: 123/9D08 Page 13 of 24 olor Depa en Ii and Environment it Pollution Health Control Division Notes to Permit Holder e a . 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day,followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: httos://www.colorado.gov/pacific./cdohe/aacc-regs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS# BIN (Ib/yr) reportable? (Ib/yr) Benzene 71432 A 1920 Yes 96 Toluene 108883 C 2240 Yes 112 Ethylbenzene 100414 C 64 No 3 001 Xylenes 1330207 C 572 Yes 29 n-Hexane 110543 C 17200 Yes 860 2,2,4-TMP 540841 C 360 Yes 18 Benzene 71432 A 2100 Yes 105 002 n-Hexane 110543 C 6600 Yes 330 Benzene 71432 A 705 Yes 227 Toluene 108883 C 3276 Yes 1054 Ethylbenzene 100414 C 256 Yes 82 003 Xylenes 1330207 C 2721 Yes 875 n-Hexane 110543 C 5507 Yes 1772 2,2,4-TMP 540841 C 293 Yes 94 Benzene 71432 A 656 Yes 656 004 Toluene 108883 C 2607 Yes 2607 Ethylbenzene 100414 C 207 No 207 AIRS ID: 12319D08 Page 14 of 24 olor DeP a en li Heal th and Environment it Pollution Control Division Xylenes 0 111 Yes 2111 n-Hexane 110543 C 4678 Yes 4678 Formaldehyde 50000 A 175 No 175 Methanol 67561 C 26 No 26 005 Acetaldehyde 75070 A 24 No 24 and Acrolein 107028 A 22 No 22 006 each Benzene 71432 A 14 No 14 1,3-Butadiene 106990 A 6 No 6 Toluene 108883 C 5 No 5 Formaldehyde 50000 A 142 No 142 Methanol 67561 C 21 No 21 Acetaldehyde 75070 A 19 No 19 007 Acrolein 107028 A 18 No 18 Benzene 71432 A 11 No 11 1,3-Butadiene 106990 A 5 No 5 Toluene 108883 C 4 No 4 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors Emission Factors Uncontrolled Controlled CAS# Pollutant lb/1000 gal lb/1000 gal Source Condensate Condensate Throughput Throughput Engineering VOC 31.4679 1.5734 calculation (WimSim + EPA Tanks) Engineering calculation 71432 Benzene 0.1143 0.0057 (WimSim + EPA Tanks) i Engineering calculation 108883 Toluene 0.1333 0.0067 (WimSim + EPA Tanks) Engineering 540841 2,2,4-TMP 0.0218 0.0011 calculation (WimSim + EPA Tanks) Engineering 1330207 Xylene 0.0340 0.0017 calculation (WimSim + EPA Tanks) AIRS ID: 123/9D08 Page 15 of 24 olo Depa en ili and Environment t PollutionHealth Control Division a issio ors Uncontrolled Controlled CAS# Pollutant lb/1000 gal lb/1000 gal Source Condensate Condensate Throughput Throughput Engineering calculation 100414 Ethylbenzene 0.0037 0.0002 +EPA im +EPA Tanks) Engineering calculation 110543 n-Hexane 1.0238 0.0512 (WimSim+EPA Tanks) Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. Point 002: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source IbIBBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.0131 CDPHE Memo 09- 0.262 02 110543 n-Hexane 0.0011 CDPHE Memo 09- 0.022 02 71432 Benzene 0.0004 CDPHE Memo 09- 0.007 02 Note: The controlled emissions factors for point 002 are based on the flare control efficiency of 95%. Point 003: Emission Factors- Emission Factors—Controlled Uncontrolled CAS Pollutant lb/1000 gal Source Lb/1000 gal Source loaded loaded VOC 5.21 AP-42 0.2605 AP-42 Engineering 0.0021 Engineering 71432 Benzene 0.0420 Calculation calculation 108883 Toluene 0.1950 Engineering 0.0098 Engineering Calculation Calculation 100414 Ethylbenzene 0.0152 Engineering 0.0008 Engineering Calculation Calculation 1330207 Xylene 0.1620 Engineering 0.0081 Engineering Calculation Calculation Engineering Engineering 110543 n-Hexane 0.3278 0164 Calculation 0. Calculation 540841 2,2,4-TMP 0.0174 Engineering 0.0009 Engineering Calculation Calculation The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: AIRS ID: 123/9D08 Page 16 of 24 olor Depa en li Health and Environment Jri Pollution Control Division L= 12.,- ID/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) 5.57 psia M (vapor molecular weight)= 65 Ib/Ib-mol T (temperature of liquid loaded) = 520°R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors by the VOC emission factor. Controlled emission factors are based on a flare efficiency of 95%. Point 004: Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 3172 294 805 407 Flanges 435 0 162 21 Open-ended Lines 25 0 0 0 Pump Seals 0 0 2 0 Valves 1225 98 809 157 Other* 434 0 65 52 I VOC Content(wt. 0.212 1 1 1 fraction) Benzene Content(wt. 0.00055 0.00807 0.00807 0.00807 fraction) Toluene Content(wt. 0.00033 0.03746 0.03746 0.03746 fraction) Ethylbenzene(wt. 0.00004 0.00293 0.00293 0.00293 fraction) Xylenes Content(wt. 0 0.03111 0.03111 0.03111 fraction) n-hexane Content(wt. 0.00205 0.06298 0.06298 0.06298 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 Water/Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 1.4E-04 1.4E-03 2.5E-04 Pump Seals 2.4E-03 NA 1.3E-02 2.4E-05 Valves 4.5E-03 8.4E-06 2.5E-03 9.8E-05 Other 8.8E-03 3.2E-05 7.5E-03 1.4E-02 Source: EPA-453/R95-017 AIRS ID: 123/9D08 Page 17 of 24 olo Depa en li Health and Environment it Pollution Control Division Compliance with im' t it on by using the TOC emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas analysis. Points 005 and 006 each: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant IbJMMBtu g/bhp-hr IbIMMBtu glbhp-hr NOx 3.0938 11.60 0.2667 1.00 CO 2.9338 11.00 0.5334 2.00 VOC 0.1867 0.70 0.1867 0.70 50000 Formaldehyde 0.0205 0.08 0.0205 0.08 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8266 Btu/hp-hr, a site-rated horsepower value of 118, and a fuel heat value of 1188 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Conservative Conservative 50000 Formaldehyde AP-42 AP-42 Point 007: Emission Factors- Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBhi g/bhp-hr lb/PAMBtu g/bhp-hr NOx 1.4501 5.92 0.6859 2.80 CO 7.9366 32.40 1.1758 4.80 VOC 0.2450 ' 1.00 0.2450 1.00 50000 Formaldehyde 0.0205 0.08 0.0205 0.08 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 I 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 9000 Btu/hp-hr, a site-rated horsepower value of 88, and a fuel heat value of 1189 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Conservative Conservative 50000 Formaldehyde AP-42 AP-42 AIRS ID: 123/9D08 Page 18 of 24 olor- Depa en f li Health and Environment ll Alik it Pollution Control Division 6) In accordance with •"_' 5-7 1, •it . missi tice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Points 005, 006 and 007: These engines are subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to include requirements for area sources and engines ≤ 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.qov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.qov/ttn/atw/area/arearules.html 8) This facility is classified as follows: I Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-hexane, total HAPS NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable NSPS OOOO Not Applicable 9) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 10) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification. AIRS ID: 123/9D08 Page 19 of 24 olo Depa en li Health and Environment it Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2.Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Altemative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary° is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five(5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9D08 Page 20 of 24 olor Depa en Ii and Environment it Pollution Health Control Division 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the 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 altemative 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.gov/cs/Satel lite/CDPHE-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: «AIRSPIant» Page 2 of 24 olo Depa en Ii Health and Environment it Pollution Control Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% O2) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology(RACT): Reg 3, Part B§ II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating intemal 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 Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich 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. AIRS ID: «AIRSPlant» Page 3 of 24 olor Depa en Ii Health and Environment it Pollution Control Division Lean burn engi• - esi ater t 00 hp shall use an oxidation catalyst to reduce emissions. The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § LB (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine(RICE) MACT: 40 CFR Part 63, Subpart ZZZZ AIRS ID: «AIRSPIant» Page 4 of 24 olo Depa en li Health and Environment it Pollution Control Division A permanent replacem I n jor so ' subject to the requirements in 40 CFR Part 63, Subpart ZZZZ.An analysis of the applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: «AIRSPlant» Page 5 of 24 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc Permit Number 14WE1288 Source Location: Five Rivers K07-62-1HN, 63-1HN, 64-1HN, K18-69HN SESE Section 8,T4N, R66W, Weld County (non-attainment) Point 001: Condensate tanks Point 002: produced water tanks Point 003: Truck loadout Equipment Description: Point 004: fugitive emissions Point 005: 4SRB Engine Point 006: 4SRB Engine Point 007: 4SRB Engine AIRS ID: 123-9D08 Date: October 29, 2014 Review Engineer: Stephanie Chaousy Control Engineer Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no"to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? July 18, 2014 Section 4—Source Description AIRS Point Equipment Description 001 Fourteen (14) above ground 538 bbl atmospheric condensate storage tanks. Emissions from these tanks are controlled by a flare. 002 Four(4) above ground 538 bbl atmospheric produced water storage tanks. Emissions from these tanks are controlled by a flare. 003 Truck Condensate Loadout 004 Fugitive VOC leak emissions Page 1 One(1) Cummins, Model G8.3, Serial Number 46851349, natural gas-fired, naturally 005 aspirated, 4SRB reciprocating internal combustion engine, site rated at 118 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR)system and air-fuel ratio control.This emission unit is used for natural gas compression. One(1) Cummins, Model G8.3, Serial Number 46438683, natural gas-fired, naturally 006 aspirated, 4SRB reciprocating internal combustion engine, site rated at 118 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control.This emission unit is used for natural gas compression. One(1)GM, Model 5.7L, Serial Number 1M02057AH, natural gas-fired, naturally 007 aspirated, 4SRB reciprocating internal combustion engine, site rated at 88 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes",for what pollutant? PM1p CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes",for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B,Section III.D.2) Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes"the provisions of X Yes No Regulation 7,Sections XII and XVII.C may apply) Point 002: Are"flash"emissions anticipated from X Yes No these tanks? Point 002: Is this tank located at an E&P site? X Yes No Point 002: Is this tank located at a non-E&P, Yes X No midstream or downstream site? Point 002: Is this source claiming exempt status for ' this source based on the fraction of oil in the stored X Yes No water(less than 1% by volume crude oil on an average annual basis)? Point 002: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 002: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC)805 Rule? Point 003: Is this source located at an oil and gas X Yes No exploration site? Point 003: If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate Yes X No (hydrocarbons that have an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Point 003: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP)emissions? Point 003: Will this equipment be operated in any X Yes No NAAQS nonattainment area? Point 003: Does this source load gasoline into Yes X No transport vehicles? Page 2 Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Source provided site-specific emission factors using gas sample,WinSim and EPA Tanks. See Section 14 for calculations. 002 CDPHE Memo 09-02 AP-42: Chapter 5.2, Equation 1 L= 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded 003 S = Saturation Factor P =true vapor pressure of liquid loaded [psia] M = molecular weight of vapors[lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] 004 EPA-453/R-95-017, Table 2-4 005 NOx, VOC, CO: Manufacturer HAPS: AP-42 006 NOx,VOC, CO: Manufacturer RAPS: AP-42 007 NOx, VOC, CO: Manufacturer HAPS: AP-42 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTEI AIRS Point Process Consumption/Throughput/Production 001 400,000 BBL per year 002 300,000 BBL per year 003 400,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 3172 294 805 407 004 Flanges 435 --- 162 21 Open-Ended Lines 25 Pump Seals --- 2 Valves 1225 98 809 157 Other 434 --- 65 52 005 7.19 MMscf/yr 006 7.19 MMscf/yr 007 5.84 MMscf/yr Basis for Permitted Emissions(Permit Limits' AIRS Point Process Consumption/Throughput/Production 001 400,000 BBL per year(Operator requesting the PTE) 002 300,000 BBL per year(Operator requesting the PTE) 003 400,000 BBL per year Page 3 Equipment Type Gas Heavy Oil(or Light Oil(or Water/Oil Heavy Liquid) Light Liquid) Connectors 3172 294 805 407 004 Flanges 435 — 162 21 Open-Ended Lines 25 — — — Pump Seals — — 2 — Valves 1225 98 809 157 Other 434 — 65 52 005 . 7.19 MMscf/yr 006 7.19 MMscf/yr 007 5.84 MMscf/yr Does this source use a control device? X Yes No %Reduction AIRS Point Process Control Device Description Granted 001 01 Flare 95 002 01 Flare 95 003 01 Flare 95 NOx: 91.4% 005 01 NSCR and AFCR CO: 81.8% NOx: 91.4% 006 01 NSCR and AFCR CO: 81.8% NOx: 52.7% 007 01 NSCR and AFCR CO: 85.2% Section 6—Emission Summary (tons per year) Point NO,, VOC CO Single HAP Total HAP 001 — 266 — 8.6 (Hexane) 11.2 002 — 39.3 — 3.3 (Hexane) 4.4 003 — 43.8 — 2.8 (hexane) 6.4 004 -- 49.7 --- 2.3(Hexane) 5.1 PTE: 005 13.2 0.8 12.5 0.09 0.1 (formaldehyde) 006 13.2 0.8 12.5 0.09 0.1 (formaldehyde) 007 5.0 0.9 27.5 0'07 0.1 (formaldehyde) TOTAL 31.4 401.3 52.5 17.0 (Hexane) 27.4 001 — 266 — 8.6 (Hexane) 11.2 002 — 39.3 — 3.3 (Hexane) 4.4 003 — 43.8 — 2.8 (hexane) 6.4 Uncontrolled point 004 — 49.7 — 2.3 (Hexane) 5.1 source emission rate: 005 13.2 0.8 12.5 0.09 0.1 (formaldehyde) 006 13.2 0.8 12.5 0.09 0.1 (formaldehyde) 007 5.0 0.9 27.5 0'07 0.1 (formaldehyde) Controlled point 001 - 13.3 - 0.4(Hexane) 0.6 Page 4 source emission rate: 002 --- 2.0 --- 0.17 (Hexane) 0.22 003 --- 14.1 --- 0.9 (hexane) 2.1 004 --- 49.7 --- 2.3 (Hexane) 5.1 005 1.1 0.8 2.3 0.09 0.1 (formaldehyde) 006 1.1 0.8 2.3 0.09 0.1 (formaldehyde) 007 2.4 0.9 4.1 0.07 • 00.1 (formaldehyde) TOTAL 4.6 81.6 8.7 3.8 (hexane) 8.3 Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions (lblyr) reportable? Rate(Iblyr) Point 001 Benzene 71432 A 1920 Yes 96 Toluene 108883 C 2240 Yes 112 Ethylbenzene 100414 C 64 No 3 Xylenes 1330207 C 572 Yes 29 n-Hexane 110543 C 17200 Yes 860 2,2,4-TMP 540841 C 360 Yes 18 Point 002 Benzene 71432 A 2100 Yes 105 n-Hexane 110543 C 6600 Yes 330 Point 003 Benzene 71432 A 705 Yes 227 Toluene 108883 C 3276 Yes 1054 Ethylbenzene 100414 C 256 Yes 82 Xylenes 1330207 C 2721 Yes 875 n-Hexane 110543 C 5507 Yes 1772 2,2,4-IMP 540841 C 293 Yes 94 Point 004 Benzene 71432 A 656 Yes 656 Toluene 108883 C 2607 Yes 2607 Ethylbenzene 100414 C 207 No 207 Xylenes 1330207 C 2111 Yes 2111 n-Hexane 110543 C 4678 Yes 4678 Points 005 and 006 each Formaldehyde 50000 A 175 No 175 Acetaldehyde 75070 A 24 No 24 Acrolein 107028 A 22 No 22 Page 5 Benzene 71432 A 14 No 14 Point 007 Formaldehyde 50000 A 142 No 142 Acetaldehyde 75070 A 19 No 19 Acrolein 107028 A 18 No 18 Benzene 71432 A 11 No 11 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section S Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? Yes X No If"yes"what kind of modification? Minor Synthetic Major Minor Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? For Reg. 3, Part B, III.C.1.a(emissions increase> 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.ii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d(synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards(NAAQS)? ( ) If"yes",for which pollutants?Why? AIRS Point Section 12—Regulatory Review _Regulation 1 -Particulate. Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which 001-007 is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Regulation 2—Odor Page 6 Section I.A- No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 001-007 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Regulation 3-APENs, Construction Permits, Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: 001-007 each individual emission point in a non-attainment area with uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant(pollutants are not summed) for which the area is non-attainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions 001-007 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg.3, Part B, Section II.D.2a) Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is/is not located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 003 The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the tank battery from which loadout is occurring will be in service after the date above, this source is considered"new or modified." Operator is using submerged fill (0.6 saturation factor), therefore, RACT requirements are satisfied. Part B, III.D.2- RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is/is not located in the 8-hour ozone nonattainment area. 004 The date of interest for determining whether the source is new or modified is therefore November 20, 2007 (the date of the 8-hour ozone NA area designation). Since the fugitives will be in service since after the date above, this source is considered"new or modified." Operator has agreed on the Division's standard conditions. Regulation 6- New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. Is this source greater than 19,800 gallons(471 bbl)?Yes 001 Is this source subject to NSPS Kb? No WHY? The storage tanks are prior to custody transfer and have a capacity less than 420,000 gallons and are therefore not subject to this regulation. 003 No applicable subpart. This facility is not a bulk gasoline terminal. NSPS OOOO: Standards of Performance for Crude Oil and Natural Gas Production, Transmission and Distribution. For fugitive emissions at natural gas processing plants subject to NSPS OOOO. This subpart establishes emission standards and compliance schedules for the control of volatile organic compounds(VOC)and 004 sulfur dioxide(SO2) emissions from affected facilities that commence construction, modification or reconstruction after August 23,2011. Is this source at a"natural gas processing plant?" No Is this source subject to NSPS OOOO? No WHY? Facility does not meet the definition of"natural gas processing plant"therefore not meeting the criteria of this subpart. Page 7 NSPS JJJJ: The date of construction is the date it was ordered or reconstructed/modified. 005,006, All engines were all manufactured before the 7/1/2008 effective date and are therefore not 007 subject to NSPS JJJJ. (dates provided: 005: February 2008; 006: June 2005; 007: February 2007) Regulation 7—Volatile Oraanic'Compound§ XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks 001,002 since it is located in a non-attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is currently subject to this since actual uncontrolled emissions are greater than 20 tpy of VOC.) No sections apply. Per Regulation 7, Section VI.C, a terminal is defined as a petroleum liquid storage and distribution facility that has a daily average throughput of more than 003 76,000 liters of gasoline(20,000 gallons), which is loaded directly into transport vehicles. This facility is neither a terminal, nor a bulk plant per definitions in Reg 7, Section VI.C. 004 Section XII.G: If facility is a natural gas processing plant located in non-attainment area,then subject to Section XII.G.Facility is not a natural gas processing plant. 005,006, Regulation No.7,Section XVII.E:engines are subject to Regulation 7 because they are 007 not subject to NSPS JJJJ. Regulation 8—Hazardous Air Pollutants MACT EEEE:Organic Liquids Distribution 001 This source is not subject to MACT EEEE because it is not located at a major source of HAP. 001 004 MACT HH This source is not subject to MACT HH because it is not located at a major source of HAP. 002, 003 None 005, 006, MACT ZZZZ: The date of construction is the first time the engine is installed at any 007 location, therefore engines are new sources subject to MACT ZZZZ. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Emission Pollutant/ Fugitive Emission Factor Source Control Description Factor CAS# (YIN) (%) 31.4679 Engineering calculation 95 lb/1000 gal VOC No (WimSim+ EPA Tanks) 0.1143 Benzene/ No Engineering calculation 95 lb/1000 gal 71432 (WimSim+EPA Tanks) 0.1333 Toluene/ Engineering calculation lb/1000 qal 108883 No (WimSim+ EPA Tanks) 95 01 E&P Condensate 0.0218 2,2,4-TMP No Engineering calculation 95 Storage Tanks lb/1000 gal /540841 (WmSim+EPA Tanks) 001 0.0340 Xylenes/ No Engineering calculation 95 lb/1000 gal 1330207 (WimSim+EPA Tanks) 0.0037 Ethylbenzene/ No Engineering calculation 95 lb/1000 gal 100414 (WimSim+ EPA Tanks) 1.0238 n-Hexane/ Engineering calculation lb/1000 gal 110543 No (WimSim+ EPA Tanks) 95 SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses 6.2381 VOC No CDPHE PS Memo 09- 95 lb/1000 gal 02 Produced Water 0.1667 CDPHE PS Memo 09- 01 Storage Tanks lb/1000 gal Benzene N0 02 95 002 0.5238 n-Hexane No CDPHE PS Memo 09- 95 lb/1000 qal 02 SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 5'21 VOC No AP-42 95 lb/10O0 gal 01 Truck loadout 0'0420 Benzene/ No Engineering calculation 95 003 lb/1000 gal 71432 0.1950 Toluene/ No Engineering calculation 95 lb/1000 gal 108883 Page 8 0.0152 Ethylhenzene/ No Engineering calculation 95 lb/1000 gal 100414 0.1620 Xylenes/ No Engineering calculation 95 lb/1000 gal 1330207 0.3278 n-Hexane/ No Engineering calculation 95 lb/1000 gal 110543 0.0174 2,2,4-TMP/ No Engineering calculation 95 lb/1000 gal 540841 SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 004 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, NA Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves,flanges, connections, seals, drains) 11.6 g/hp- NOx No Manufacturer 91.4 hr 005 0.7 g/hp-hr VOC No Manufacturer 0 and 01 4SRB Engine 11.0 g/hp- CO No Manufacturer 81.8 006 hr each 0.0205 Formaldehyde No AP-42 0 lb/mmbtu /50000 SCC 20200253: 4-cycle rich bum 5.92 g/hp- NOx No Manufacturer 52.7 hr 1.0 g/hp-hr VOC No Manufacturer 0 01 4SRB Engine 32.4 g/hp- CO No Manufacturer 85.2 007 hr 0.0205 Formaldehyde No AP-42 0 Ib/mmbtu /50000 SCC 20200253: 4-cycle rich bum Section 14—Miscellaneous Application Notes AIRS Point 001 Condensate Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). Emissions were calculated using site-specific emission factors from EPA Tanks (working and breathing) and WinSim Design II model (flashing). Two gas analyses were used in the model for calculating the • flash losses. Sampled on June 6, 2014 (within a year of application submittal). Uncontrolled emission factors with 500,000 bbl/yr: Component Uncontrolled Uncontrolled Emission Emission Total Total emission emissions- emissions- factor-EPA factor- Emission factor-(lb/1000 EPA Tanks WinSim Tanks WinSim factor— gal) (TPY) (TPY) (lb/bbl) (lb/bbl) (lb/bbl) VOC 71.09 193.24 0.36 0.97 1.3216 31.4679 Benzene 0.164 0.801 0.0008 0.004 0.0048 0.1143 n-hexane 2.08 6.58 0.01 0.033 0.043 1.0238 Operator calculated toluene, ethylbenzene, 2,2,4-TMP and xylenes from WinSim: Component Uncontrolled Uncontrolled Total Total Total Total Operator emissions- emissions- emissions emissions Emission emission emissions EPA Tanks WinSim (TPY) (Ib/yr) factor— factor- (lb/yr) (TPY) (TPY) (lb/bbl) (lb/1000 gal) Toluene 0.222 0.898 1.12 2240 0.0056 0.1333 2240 2,2,4-TMP 0.041 0.142 0.183 366 0.00092 0.0218 360 Xylenes 0.054 0.232 0.286 572 0.0014 0.0340 572 Ethyl benzene 0.006 0.025 0.31 62 0.00016 _0.0037 64 Page 9 AIRS Point 002 Produced Water Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors(Ib/I000 gal) VOC Benzene n-Hexane lrapahg8,Boulder,Broomfield, Delver, 62381; `O-1667 (,5r238r? = `Jef r n,.Lathier and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 AIRS Point 003 Truck Condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 5.57 Psia Based on EPA TANKs run M 65 Lb/lb-mole Based on EPA TANKs run T 520 Deg R Based on EPA TANKs run L 5.21 Lb/10^3 gal 2.19E-01 Lb/bbl This value is used to calculate annual emissions AP-42: Chapter 5.2 Equation 1 L= 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S=Saturation Factor P=true vapor pressure of liquid loaded[psia] M =molecular weight of vapors[IbAb-mole] T=temperature of bulk liquid loaded[deg. R] L 5.21lb/10^3 gal 2.19E-011b/bbl Annual requested Throughput 16800000gal/yr Annual requested VOC emissions 874471b/yr 43.72tpy' *Operator calculated 43.8 TPY. I will use that in my calculations/permit HAP emissions were calculated using HAP weight%from the Five Rivers K07-63-1 HN low pressure separator extended condensate analysis sampled 6/6/2014. Component Component Uncontrolled Controlled Emission Emission wt% (lb/yr) (lb/yr)- factor factor(lb/1000 67.8082% (lb/bbl) gal) Benzene 0.8066 705.35 227.06 0.00176 0.0420 Toluene 3.7461 3275.84 1054.55 0.00819 0.1950 Ethylbenzene 0.2929 256.13 82.45 0.00064 0.0152 Xylenes 3.1114 2720.82 875.88 0.0068 0.1620 n-hexane 6.2983 5507.40 1772.93 0.01377 0.3278 2,2,4-TMP 0.3346 292.60 94.1932 0.00073 0.0174 Only 10 of the 14 tanks are controlled with vapor return lines(which is calculated to 285,600 bbVyr). This equates to 31.2 TPY. This controlled at 95%gives 1.56 TPY+ (42.7-31.2)= 14.06 TPY=> 14.1 TPY controlled VOC(which equates to approximately 67.8082%overall). Page 10 AIRS Point 004 Fugitive VOC Leak Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY(permit threshold). AIRS Point 005 4SRB A permit will be issued because criteria pollutants are greater than 1 TPY and the facility-wide uncontrolled criteria pollutant emissions are greater than 5 TPY(permit threshold). AIRS Point 006 4SRB A permit will be issued because criteria pollutants are greater than 1 TPY and the facility-wide uncontrolled criteria pollutant emissions are greater than 5 TPY(permit threshold). AIRS Point 007 4SRB A permit will be issued because criteria pollutants are greater than 1 TPY and the facility-wide uncontrolled criteria pollutant emissions are greater than 5 TPY(permit threshold). Page 11 Air Pollutant Emission Notice(APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY- Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) -- _� MRS ID#2: I Z5 . 913PR- ;qI ❑ APEN update onlys JUL 182014 ® New or previously unreported battery ❑ Modification to existing source6 ❑ Previously grandfathered battery3 ❑ Registration for coverage under general permit no.GPOFin = sw cc ® Synthetic minor facility &cancellation request for individual permit ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no. GPOI ❑ Administrative permit amendments ❑ Permitted under indilidualpermit: ]4 OE 12$g ❑ Other: For individual permit applications,check if you want': ❑A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Name10: Noble Energy,Inc. OGCC Operator#: 100322 Mailing Address": 1625 Broadway,Suite 2200 mputney@nobleenergy City: Denver State: CO Zip: 80027 E-mail: inc.com Contact Name: Mike Putney Phone: 303-228-4385 Fax: 303-228-4280 Tank Battery Name12: Five Rivers K07-62-IHN,63-1HN,64-1HN,K18-69HN Number of tanks: 14 Location13(QQ Sec.Twp.Range.): SESE SEC8 T4N R66W County: Weld Total tank capacity[bbl]: 7532 Calendar year for which"Actual"data applies14: 2014 Year(s)tank(s)were placed in service's: 2014 Control Description1s: FLARE(Vapor Combustors) Control Efficiency's: 95% Condensate Throughput's[bbl/year] Requested': 400,000 Maximum for PTE calculation°: 400,000 Actual21: While Controls Operational22 Other equipment at facility23: Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit EI Check if site-specific emission factors provided to calculate emissions24. Emission Factor Battery Requested Emissions19 Actual Emissions2' Pollutant25 [Ib/bbl] PTE26 Uncontrolled./ Controlled28 Uncontrolled27 Controlled2s VOC[tons/year] 1.33 266 266 13.3 NOx[tons/year] CO[tons/year] Benzene[lbs/year] 0.0048 1920 1920 96 n-Hexane[lbs/year] 0.043 17,200 17,200 860 Wells serviced by this tank or tank battery29 API#: 05-123-38086 Name: Five Rivers K07-62-IHN 0 Newly Reported Well API#: 05-123-38257 Name: Five Rivers K07-63-IHN 0 Newly Reported Well API#: 05-123-38076 Name: Five Rivers K07-64-1HN ®Newly Reported Well API#: 05-123-38069 Name: Five Rivers K18-691119 0 Newly Reported Well API#: Name ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: ❑Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief If this is a registration for coverage under general permit GP01,I further certify that this source is and will be operated in full compliance with each condition of general permit GPO1. 7 j° - 14 7/17/14 Signature of Legally Authonzed Persun-(liot a vendor or consultant) Date Mike Putney Environmental Engineer III Type or Print Name of Person Signing Above Official Title Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B 1 J q 14 A7! (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South �7 .L registration to: Denver,CO 80246-1530 FORM APCD-205 I Page 1 of 2 Five Rivers K07,KI8 Cond Tanks APEN • a) Ta as U N ` O Q O N a 'N N a C N 7 G O` LE CO Q U CD N V Z o N r CO la a CI) •O Q N p O = 7 _O �n 7 Q ° ® co ` Q d LO O c T a) T W co co town p O) Visz 7 v ti J Z N co Q r N 0 O W C O CI a N N 10 N M �� O > N Z > co M 0 0 0 4 N a) Z C 7 V 'V' O E a O m c, N c 46 C a C coN U) � N ZZZ n d °` U) N ° 0EE I- F- � r > co , c.) 7 7 •y O et) et) 05 O W 'E Z Z w � E E E W o oc as LLo _c W F- a a Z E --; Q c . U O y eY p z 'C `V ��4, U 0) .Q J c CO C p 5 J V co C ain = .0 iiY O ' r o da o f�J w m Y •w ) d o Z W `� 0 c O4 0 o a a 2 d v d o Q ". N : 4 C T a) as 0 J ° ` i E •7il- c o ` o O co W a) r V O• O ≥. co Q y (() . W N 0. 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