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Home My WebLink About20143950.tiff ,* CDPHE COLORADO CO A Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 O St PO Box 758 RECEIVED Greeley, CO 80632 December 16, 2014 DEC 19 201k WELD COUNTY CONMISSIONF^` Dear Sir or Madam: On December 17, 2014, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - Sater CC18-72-1HN, 74-1HN. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health 0. Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure !o� cat ,/,‘9-411.,1P\ 4300 Cherry Creek Drive S., Denver,CO 80246-1530 P 303-692.2000 www.colorado.gov/cdphe � / Yom « , John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ( Ikl r*� �1tfR�ie 144 CC 2014-3950 CDPHE Air Pollution Control Division CO slr Notice of a Proposed Project or Activity Warranting Public ' Comment Website Title: Noble Energy, Inc. - water CC18-72-1HN, 74-1HN - Weld County Notice Period Begins: December 17, 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: Sater CC18-72-1 HN, 74-1HN • Oil and gas exploration and production facility SWSE Section 18, T4N, R63W 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 fugitives. 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 14WE1409 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 /�� COLORADO 1 I LJyL► kw,=-;„ STATE OF COLORADO oc•Co „� \ COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT _ -4, AIR POLLUTION CONTROL DIVISION o' TELEPHONE:(303)692-3150 */876_. CONSTRUCTION PERMIT PERMIT NO: 14WE1409 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 Sater CC18-72-1 HN, 73-1 HN, 74-1 HN Battery, located in the SWSE Section 18, T4N, R63W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Tank Ten (10) above ground 300 bbl atmospheric condensate Battery 001 storage tanks. Emissions from these tanks are controlled by a flare. PW Three (3) above ground 300 bbl atmospheric produced water 002 storage tanks. Emissions from these tanks are controlled by a 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 G5.9, Serial Number 2LB016630, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP1 005 internal combustion engine, site rated at 84 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 G5.9, Serial Number 46813588, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP2 006 internal combustion engine, site rated at 84 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: 123/9D20 Page 1 of 21 Fugitive SM/M Version 2012-2 olor Depa en li Health and Environment it Pollution Control Division Facility AIRS Equipment Point Description ID One (1) GM, Model 5.7L, Serial Number 1M06076AH, 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: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Cummins G5.9 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 sect), 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. 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). 2. 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.) 3. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 4. 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 AIRS ID: 123/9D20 Page 2 of 21 olor Depa en li Health and Environment it Pollution Control Division 5. 11 Emissions of ;e,- -nt II a wing ' tions (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NOx VOC CO Tank Battery 001 4.0 --- Point PW 002 --- 1.0 Point TLO 003 --- 2.0 Point Fugitives 004 --- 45.5 --- Fugitive COMP1 005 2.3 0.8 3.9 Point COMP2 006 2.3 0.8 3.9 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. 6. 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. 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.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID Tank Battery 001 Enclosed flare VOC and HAPS AIRS ID: 12319D20 Page 3 of 21 olor Depa en Ii Health and Environment it Pollution Control Division PW En 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. PROCESS LIMITATIONS AND RECORDS 8. 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 300,000 BBL 002 Produced water throughput 150,000 BBL 003 Condensate Loading 300,000 BBL 005 Consumption of natural gas as a fuel 4.62 MMscf/yr 006 Consumption of natural gas as a fuel 4.62 MMscf/yr 007 Consumption of natural gas as a fuel 5.51 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 9. Visible emissions shall not exceed twenty percent(20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation ' No. 1, Section II.A.1. &4.) 10. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 11. 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 AIRS ID: 123/9D20 Page 4 of 21 olor- en Depa li Health and Environment ' A it Pollution Control Division means of vis w€ a o tut end 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. 12. 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. 13. 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. 14. 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) 15. 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. b. All compartment hatches (including thief hatches) shall be closed and latched at all times when loading operations are not active, except for periods of maintenance, gauging, or safety of personnel and equipment. c. The owner or operator shall inspect loading equipment and operations onsite at the time of inspections to monitor compliance with Condition 15 (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. 16. 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. 17. 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. 18. 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: AIRS ID: 12319D20 Page 5 of 21 olor Depa en Ii Health and Environment it Pollution Control Division a. Direct cti na escr' below shall satisfy the requirement to apply RACT. i. Auditory/visual/olfactory inspection (AVO) will be performed on a quarterly basis. ii. For each leak found in the AVO inspection, a gas detector 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. iii. For repair, valves adjacent to the equipment to be repaired will be closed if practicable, minimizing the volume released. iv. Repaired components shall be re-screened using AVO to determine if the leak is repaired. v. The following records shall be maintained for a period of two years: • The name of the site screened via AVO inspection and the name of the inspector. • Components evaluated with the gas detector. • Repair methods applied. • Dates of the AVO inspections, gas detector calibrations, attempted repairs, successful repairs, repair delays, and post- repair screenings. vi. Leaks shall be repaired as soon as practicable, but no later than 15 calendar days after detection, unless it is technically or operationally infeasible to make the repair within 15 calendar days. Records documenting the rationale shall be maintained if it is technically or operationally infeasible to make the repair within 15 calendar days. 19. Points 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 AIRS ID: 123/9D20 Page 6 of 21 olor. Depa en a li "'Health and Environment •it Pollution Control Division at_ wi ≥100HP _=vL J .=�:ry F1 " ,8 a ....,a8 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 1 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. OPERATING & MAINTENANCE REQUIREMENTS 20. 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.) 21. Point 003: Flare shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare, or by other convenient means approved by the Division, determine whether the flare is operating properly. 22. Point 003: The owner or operator of a loadout to control emissions shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Install dry-break loading couplings to prevent hydrocarbon liquid loss during uncoupling from vehicles. d. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. e. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. f. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. g. Inspect pressure relief devices (PRD) annually for proper operation and replace as necessary. PRDs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. h. Document annual inspections of thief hatch seals and PRD with an indication of status, a description of any problems found, and their resolution. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 23. 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 AIRS ID: 123/9D20 Page 7 of 21 • Depa en li Health and Environment Tit Pollution Control Division duration greaDolor t 1) any f (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.All) 24. 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", "water/oil service" and "gas service". The operator shall submit the results to the Division as part of the self-certification process to ensure compliance with emissions limits. 25. 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 26. 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. 27. Points 005, 006 and 007: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. ADDITIONAL REQUIREMENTS 28. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5)tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOX) 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 AIRS ID: 123/9D20 Page 8 of 21 olor , iDepa en .f • .Ii Health" and Environment �m. • it Pollution Control Division For so, ' -. itt• t 0'`. • - pe..:: ,,, more t: ange in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity;,or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. 29. 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 30. 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. 31. 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. 32. 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. 33. 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. AIRS ID: 123/9D20 Page 9 of 21 Depa en li Health and Environment it Pollution Control Division 34. Each and evDolor it i al pa of and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 35. 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. 36. 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, reciprocating internal combustion engines and associated fugitives at a synthetic minor facility. AIRS ID: 123/9D20 Page 10 of 21 i olor-i Depa en . - .li Health and Environment If Pollution Control Division Notes to Permit Holder- = me o •e ' "" an -. 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: https://www.colorado.gov/pacific/cdphe/agcc-reqs 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 612 Yes 31 Toluene 108883 C 456 Yes 23 001 2,2,4-TMP 540841 C 30 No 2 Xylenes 1330207 C 136 No 7 n-Hexane 110543 C 5140 Yes 257 Benzene 71432 A 1050 Yes 53 002 n-Hexane 110543 C 3300 Yes 165 Benzene 71432 A 685 Yes 34 Toluene 108883 C 2060 Yes 103 003 Ethylbenzene 100414 C 402 Yes 20 Xylenes 1330207 C 2303 Yes 115 n-Hexane 110543 C 4657 Yes 233 Benzene 71432 A 575 Yes 575 Toluene 108883 C 1505 Yes 1505 004 Ethylbenzene 100414 C 289 Yes 289 Xylenes 1330207 C 1630 Yes 1630 n-Hexane 110543 C 3643 Yes 3643 AIRS ID: 123/9D20 Page 11 of 21 Dolor Depa en li Health and Environment it Pollution Control Division Formald 119 No 119 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 005 Acrolein 107028 A 15 No 15 Benzene 71432 A 9 No 9 1,3-Butadiene 106990 A 4 No 4 Toluene 108883 C 3 No 3 Formaldehyde 50000 A 119 No 119 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 006 Acrolein 107028 A 15 No 15 Benzene 71432 A 9 No 9 1,3-Butadiene r 106990 A 4 No 4 Toluene 108883 C 3 No 3 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 12.6190 0.6310 calculation (WimSim+ EPA Tanks) Engineering 71432 Benzene 0.0476 0.0024 calculation (WimSim + EPA Tanks) Engineering 108883 Toluene 0.0357 0.0018 calculation (WimSim+ EPA Tanks) AIRS ID: 12 3/9D20 Page 12 of 21 :101 Depa en� i' a _a" ac isslo :,. ors Uncontrolled Controlled CAS# Pollutant lb/1000 gal lb/1000 gal Source Condensate Condensate Throughput Throughput Engineering 540841 2,2,4-TMP 0.0024 0.0001 calculation (WimSim + EPA Tanks) Engineering 1330207 Xylene 0.0110 0.0006 calculation (WimSim + EPA Tanks) - Engineering 110543 n-Hexane 0.4048 0.0202 calculation (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 lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.0131 Source 110543 n-Hexane 0.022 0.0011 Source 71432 Benzene 0.007 0.0004 Source 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 6.4 AP-42 0.32 AP-42 71432 Benzene 0.0544 Engineering 0.0027 Engineering Calculation Calculation 108883 Toluene 0.1635 Engineering 0.0082 Engineering Calculation Calculation 100414 Ethylbenzene 0.0319 Engineering 0.0016 Engineering Calculation Calculation 1330207 Xylene 0.1828 Engineering 0.0091 Engineering Calculation Calculation 110543 n-Hexane 0.3696 Engineering 0.0185 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: L = 12.46*S*P*M/T AIRS ID: 123/9D20 Page 13 of 21 R: AePF li Health and Environment it Pollution Control Division S =0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) 6.845 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. Point 004: • Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2441 294 627 256 Flanges 396 -- 158 16 Open-ended Lines 23 -- — — Pump Seals — -- 2 — Valves 1053 98 708 109 Other' 334 --- 59 35 VOC Content(wt. 0.214 1 1 1 fraction) Benzene Content(wt. 0.00059 0.008501 0.008501 0.008501 fraction) Toluene Content(wt 0.0004 0.025554 0.025554 0.025554 fraction) Ethylbenzene(wt. 0.00005 0.00499 0.00499 0.00499 fraction) Xylenes Content(wt. 0.00012 0.028574 0.028574 0.028574 fraction) n-hexane Content(wt. 0.00239 0.05777 0.05777 0.05777 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 Compliance with emissions limits in this permit will be demonstrated by using the TOC emission factors listed in the table above with representative component counts, multiplied by-the VOC content from the most recent gas analysis. AIRS ID: 123/9O20 Page 14 of 21 Iolor.A Depa en .f • di 'Health and Environment r` it Pollution Control Division Points 005 and 00-- Emission Factors - Emission Factors— Uncontrol led Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 3.1785 11.41 0.7800 2.80 CO 4.0783 14.64 1.3371 4.80 VOC 0.2786 1.00 0.2786 1.00 50000 Formaldehyde 0.0205 0.07 0.0205 0.07 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 7914 Btu/hp-hr, a site-rated horsepower value of 84, and a fuel heat value of 1200 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- Uncontrolled Emission Factors—Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu 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 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 1200 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 6) Point 005: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting — effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ia08.odf AIRS ID: 123/9D20 Page 15 of 21 olor Depa en Ii Health and Environment it Pollution Control Division 7) Points 005, 006 a gi su CFR, 3, Subpart 7777- 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: htto://www.epa.aov/ttn/atw/area/fr18ia08.odf Additional information regarding area source standards can be found on the EPA website at: http://www.eoa.aov/ttn/atw/area/arearules.html 8) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year tens 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. 9) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-hexane NANSR Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable NSPS OOOO Not Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://eckgpoaccess.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 XXXXX.( 11) 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-selfcertification. AIRS ID: 123/9D20 Page 16 of 21 �, , olor- 1 Depa en . • Ii Health and Environment A 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-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9D20 Page 17 of 21 olo Depa en Ii Health and Environment it Pollution 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 alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition,if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7)calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol(ver March 2006 or newer)as found on the Division's web site at: htto://www.co l orado.q ov/cs/Satel l ite/C D P H E-AP/C BO N/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year(whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year(8760), whichever applies. AIRS ID: 123/9D20 Page 2 of 21 - olor4 Depa en li 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 internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ SO2: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. AIRS ID: 123/9D20 Page 3 of 21 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 XVILE—State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 500<Hp July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean bum engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for •lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, them will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part 8, § I.B (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine(RICE)MACT:40 CFR Part 63, Subpart 7777 AIRS ID: 123/9D20 Page 4 of 21 olor Depa en li Health and Environment it Pollution Control Division A permanent replacem -_ to a an 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: 12319D20 Page 5 of 21 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc Permit Number: 14WE1409 Source Location: Sater CC18-72-1HN, 73-1HN, 74-1HN Battery SWSE Section 18,T4N, R63W, 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: RICE Point 006: RICE Point 007: RICE AIRS ID: 123-9D20 Date: November 19, 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? August 21, 2014 Section 4—Source Description AIRS Point Equipment Description 001 Ten (10)above ground 300 bbl atmospheric condensate storage tanks. Emissions from these tanks are controlled by a flare. 002 Three (3) above ground 300 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 G5.9, Serial Number 2LB016630, natural gas-fired, naturally 005 aspirated, 4SRB reciprocating internal combustion engine, site rated at 84 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 G5.9, Serial Number 46813588, natural gas-fired, naturally 006 aspirated, 4SRB reciprocating internal combustion engine, site rated at 84 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 1M06076AH, 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? PMio 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 PKo 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 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? 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 003 L=loading losses in lb per 1000 gallons loaded S =Saturation Factor P=true vapor pressure of liquid loaded [psia] M =molecular weight of vapors[lb/lb-mole] T=temperature of bulk liquid loaded[deg. R] 004 EPA-453/R-95-017, Table 2-4 Page 2 NOx, CO: Manufacturer 005 VOC: Conservative estimate HAPS: AP-42 NOx, CO: Manufacturer 006 VOC: Conservative estimate HAPS: AP-42 NOx, CO: Manufacturer 007 VOC: Conservative estimate HAPS: AP-42 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 300,000 BBL per year 002 150,000 BBL per year 003 300,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2441 294 627 256 004 Flanges 396 --- 158 16 Open-Ended Lines 23 --- --- --- Pump Seals --- 2 --- Valves 1053 98 708 109 Other 334 --- 59 35 005 4.62 MMscf/yr 006 4.62 MMscf/yr 007 5.78 MMscf/yr Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 300,000 BBL per year(Operator requesting the PTE) 002 150,000 BBL per year(Operator requesting the PTE) 003 300,000 BBL per year Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2441 294 627 256 004 Flanges 396 --- 158 16 Open-Ended Lines 23 --- --- --- Pump Seals --- --- 2 --- Valves 1053 98 708 109 Other 334 --- 59 35 005 4.62 MMscf/yr 006 4.62 MMscf/yr 007 5.78 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 Page 3 003 01 Flare 95 005 01 NSCR and AFCR NOx: 75.5% CO: 67.2% 006 01 NSCR and AFCR NOx: 75.5% CO: 67.2% 007 01 NSCR and AFCR NOx: 52.7% CO: 85.2% Section 6—Emission Summary(tons per year) Point NO, VOC CO Single HAP Total HAP 001 -- 79.5 --- 2.6 (Hexane) 3.2 002 — 19.7 -- 1.7 (Hexane) 2.2 003 - 40.3 — 2.3 (hexane) 5.1 PTE: 004 — 45.5 — 1.8 (Hexane) 3.8 005 9.3 0.8 11.9 0.06 (formaldehyde) 0.08 006 9.3 0.8 11.9 0.06 0.08 (formaldehyde) 007 5.0 0.9 27.5 0.07 0.1 (formaldehyde) 001 — 79.5 — 2.6(Hexane) 3.2 002 — 19.7 — 1.7(Hexane) 2.2 003 -- 40.3 — 2.3 (hexane) 5.1 Uncontrolled point 004 -- 45.5 — 1.8 (Hexane) 3.8 source emission rate: 005 9.3 0.8 11.9 0.06 0.08 (formaldehyde) 006 9.3 0.8 11.9 0.06 (formaldehyde) 0.08 007 5.0 0.9 27.5 0.07 0.1 (formaldehyde) 001 --- 4.0 --- 0.13 (Hexane) 0.16 002 - 1.0 - 0.08 (Hexane) 0.11 003 - 2.0 - 0.12 (hexane) 0.25 Controlled point 004 — 45.5 — 1.8 (Hexane) 3.8 source emission rate: 0.06 005 2.3 0.8 3.9 (formaldehyde) 0.08 006 2.3 0.8 3.9 0.06 0.08 (formaldehyde) 007 2.4 0.9 4.1 0.07 0.1 (formaldehyde) Section 7—Non-Criteria I Hazardous Air Pollutants Uncontrolled An ve Controlled Emission Pollutant CAS# BIN Emission Rate amens (IbNr) report mal Rate(Ib/yr) Point 001 Benzene 71432 A 612 Yes 31 Toluene 108883 C 456 Yes 23 2,2,4-IMP 540841 C 30 No 2 Page 4 Xylenes 1330207 C 136 No 7 n-Hexane 110543 C 5140 Yes 257 Point 002 Benzene 71432 A 1050 Yes 53 n-Hexane 110543 C 3300 Yes 165 Point 003 Benzene 71432 A 685 Yes 34 Toluene 108883 C 2060 Yes 103 Ethylbenzene 100414 C 402 Yes 20 Xylenes 1330207 C 2303 Yes 115 n-Hexane 110543 C 4657 Yes 233 Point 004 Benzene 71432 A 575 Yes 575 Toluene 108883 C 1505 Yes 1505 Ethylbenzene 100414 C 289 Yes 289 Xylenes 1330207 C 1630 Yes 1630 n-Hexane 110543 C 3643 Yes 3643 Points 005 and 006 each Formaldehyde 50000 A 119 No 119 Acetaldehyde 75070 A 16 No 16 Acrolein 107028 A 15 No 15 Benzene 71432 A 9 No 9 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 ll.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001, 002 01 Opacity Reference: Regulation No. 7 Section Method 22 XVII.All 004 01 VOC, State only requirement Hard component HAPS count 005, 006, 01 NOx, CO Regulation No. 3, Part B.,Section III.G.3 Stack test 007 Page 5 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: 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 pennit since uncontrolled VOC emissions from this facility am greater than the 2.0 TPY threshold(Reg.3, Part B, Section lLD.2a) Page 6 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 since 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. 001 Is this source greater than 19,800 gallons (471 bbl)? No Is this source subject to NSPS Kb? No WHY? The storage tanks do not meet the criteria of this subpart; therefore not subject. 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. NSPS JJJJ: the date of construction is the date it was ordered or reconstructed/modified. 005 Point 005 were manufactured after the 7/1/2008 effective date and are therefore subject to this subpart. Re.ulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is subject to the emission control requirements for condensate tanks 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 6 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. 006, 007 Since engines are not subject to NSPS JJJJ, it is subject to the requirements of Reg 7. 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. Page 7 002, 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 for 7777 applicability. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Emission Pollutant/ Fugitive Emission Factor Source Control Description Factor CAS# (Y/N) (%) 12.6190 VOC No Engineering calculation 95 lb/1000 gal (WimSim+ EPA Tanks) 0.0476 Benzene/ Engineering calculation lb/1000 gal 71432 No (WimSim+ EPA Tanks) 95 0.0357 Toluene/ No Engineering calculation 95 01 E&P Condensate lb/1000 gal 108883 (WimSim+ EPA Tanks) Storage Tanks 0.0024 2,2,4-TMP Engineering calculation 001 lb/1000 gal /540841 No (WimSim+ EPA Tanks) 95 0.0110 Xylenes/ Engineering calculation lb/1000 gal 1330207 No (WimSim+ EPA Tanks) 95 0.4048 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 CDPHE PS Memo 09- lb/1000 gal VOC No 02 95 01 Produced Water 0.1667 Benzene No CDPHE PS Memo 09- 95 002 Storage Tanks lb/1000 gal 02 lb/1000n-Hexane No CDPHE PS Memo 09- 95 1000 gal 02 SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 6.41W1000 VOC No AP-42 95 gal 0.0544 Benzene/ No Engineering calculation 95 lb/1000 gal 71432 0.1635 Toluene/ No Engineering calculation 95 01 Truck loadout lb/1000 gal 108883 0.0319 2,2,4-TMP 003 lb/1000 gal /540841 No Engineering calculation 95 0.1828 Xylenes/ No Engineering calculation 95 lb/1000 gal 1330207 _ _ 0.3696 n-Hexane/ No Engineering calculation 95 lb/1000 gal 110543 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) 11.41 gmp NOx No Manufacturer 75.5 hr 14.64 g 'I CO No Manufacturer 67.2 01 RICE hr 005 1.0 g/hp-hr VOC No Conservative estimate 0 0.0205 Fomraldehyde No AP-42 0 lb/mmbtu /50000 SCC 20200253—4-cycle rich burn 11.41 gRlp NOx No Manufacturer 75.5 hr 14.64 gRlp CO No Manufacturer 67.2 01 RICE hr 006 1.0 g/hp-hr VOC No Conservative estimate 0 0.0205 Formaldehyde No AP-42 0 - lb/mmbtu /50000 scc 20200253—4-cycle rich burn Page 8 5.92 g/hp- NOx No Manufacturer 52.7 hr 32.4 g/hp- CO No Manufacturer 85.2 01 RICE hr 1.0 g/hp-hr VOC No Conservative estimate 0 007 0.0205 Formaldehyde No AP-42 0 Ib/mmbtu /50000 SCC 20200253—4-cycle rich burn 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). Tow gas analyses were used in the model for calculating the flash losses. Sampled on June 17, 2014 (within a year of application submittal). Uncontrolled emission factors with 300,000 bbl/yr: Component Uncontrolled Uncontrolled Uncontrolled Emission Emission Total Total emissions- emissions- emissions factor-EPA factor- Emission emission EPA Tanks WinSim (Ib/yr) Tanks WinSim factor— factor- (TPY) (TPY) (lb/bbl) (lb/bbl) (lb/bbl) (lb/1000 gal) VOC 36.68 40.2 -- 0.26 0.27 0.53 12.6190 Benzene 0.093 0.213 612 0.0006 0.0014 0.002 0.0476 Toluene 0.078 0.15 456 0.0005 0.0010 0.0015 0.0357 Ethylbenzene 0.005 0.01 30 0.00003 0.00007 0.00010 0.0024 Xylenes 0.022 0.046 136 0.00015 0.00031 0.00046 0.0110 n-hexane 1.03 1.54 5140 0.007 0.010 0.017 0.4048 2,2,4-TMP 0.035 0.057 184 0.0002 0.0004 0.0006 0.0143 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 (lb/1000 gal) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson, Lamer and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 Page 9 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 Lb/10^3 gal This value is used to 6.40 calculate annual emissions 0.269 Lb/bbl 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[Ib/Ib-mole] T= temperature of bulk liquid loaded [deg. R] L 6.401b/10^3 gal 2.69E-01 lb/bbl Annual requested Throughput 12600000ga1/yr Annual requested VOC emissions 805981b/yr 40.30tpy HAP emissions were calculated using HAP weight%from the Sater CC18-72-1HN low pressure separator extended condensate analysis. Component Component wt% Uncontrolled (Ib/yr) Emission factor Emission factor (lb/bbl) (lb/1000 gal) Benzene 0.8501 685 0.00228 0.0544 Toluene 2.5554 2060 0.00687 0.1635 Ethylbenzene 0.4990 402 0.00134 0.0319 Xylenes 2.8574 2303 0.00768 0.1828 n-hexane 5.7777 4657 0.01552 0.3696 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 RICE A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit threshold). AIRS Point 006 RICE A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit threshold). AIRS Point 007 RICE A permit will be issued because the uncontrolled CO emissions are greater than 5 TPY(permit threshold). Page 10 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) AIRS ID#': 12 D 3 I e Z 10a 1 ❑ APEN update only° ® New or previously unreported battery ❑ Modification to existing sources ❑ Previously grandfathered battery ❑ Registration for coverage under general permit no.GPOI and ® Synthetic minor facility cancellation request for individual permit': ® Located in the 8-hr Ozone Control Areas ® Application for or Modification of an individual permit ❑ Registered under general permit no. GPOI O Administrative permit amendment' ❑ Permitted under individual permit: 14WEi'4 9 ❑ Other: For individual permit applications,check if you want': O A copy of the preliminary analysis conducted by the Division 0 To review a draft of the permit prior to issuance Company Names: Noble Energy,Inc OGCC Operator#: 100322 Mailing Address'°: 1625 Broadway Suite 2200 .c City: Denver State: CO Zip: 80202 E-mail: .com utneycn nobteenergyinc Contact Name: Mike Putney Phone: (303)228-4385 Fax: (303)228-4286 Tank Battery Name'': Sater CC18-72-I HN,73-1 HN,74-1HN Battery Number of tanks: 10 Location12(QQ Sec.Twp.Range.): SWSE SEC18 T4N R63W County: Weld Total tank capacity[bbl]: 3,000 Calendar year for which"Actual"data applies1s: 2014 Year(s)tank(s)were placed in service14: 2014 Control Description's: FLARE(Vapor Combustors) Control Efficiency's: 95% Condensate Throughput"[bbl/year] Requested": 300,000 Maximum for PTE calculation19: 300,000 Actual20: While Controls Operational2' Other equipment at facility": Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. 0 Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested Emissions Actual Emissions20 Pollutant24 [lb/bbl] PTE25 Uncontrolled26 Controlled' Uncontrolled26 Controlled' VOC[tons/year] 0.53 79.5 79.5 3.98 NOx[tons/year] CO[tons/year] Benzene[lbs/year] 0.0020 600 600 30 n-Hexane ribs/year] 0.017 5100 5100 255 Wells serviced by this tank or tank battery° API#: 05-123-37985 Name: Sater CC18-72-11-IN ®Newly Reported Well 05-123-37984 SaterCC18-73-1HN API#:Name: A 0 Newly Reported Well 05-123-37983 SaterCC18-74-IHN < s" n\'Ls) 0NewlyReportedWell API#: Name: �% Is API#: Name: I. - ❑Newly Reported Well API#: Name \ 7�--,;.cc`s O Newly Reported Well API#: Name: �-- ❑Newly Reported Well API#: Name: ❑Newly Reported Well API#: Name: O Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief. If this is a registration for coverage under general permit GP I,I further certify that this source is and will be operated in full com ianc with eac/}�and i f general permit GP 1. [- ( l+[), 8/20/14 Signature of Legally Authorized P- on(not 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 (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South geistration to: Denver,CO 80246-1530 316663 FORM APCD-205 Page 1 of 2 SATER CC18-72,73,74 APEN COND TANK BATT Tti as a) 0 V InN � Q O al T a •y N a N N T C co Q ry -E. in v N 0 0 Q U Z Cr` 0 N 13 4) W M U tv a CON N Q N a C0 0 Q O N 0 Q .(41 N >. 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