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Home My WebLink About20142250.tiff STATE OF COLORADO John W.Hickenlooper,Governor oe•co� Larryctiv MD,MSPH ,�� - Executive Director and Chief Medical Officer re vC Dedicated to protecting and improving the health and environment of the people of Colorado . .1 047* 4300 Cherry Creek Dr.S. Laboratory Services Division X.1876 8✓✓✓ Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.coiorado.gov/cdphe and Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 RECEIVED • July 16, 2014 JUL 2 3 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On July 22, 2014,the Air Pollution Control Division will publish a public notice for Noble Energy, Inc— Timbro State LDl6 Econode, in the The Greeley Tribune.A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health&Environment APCD-SS-B 1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, /t lJ ta.„/ Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 6114-4.1.)t-01. t .) kirk-Inaeb) 2014-2250 - 30 -iq f 7-23 -i4 STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk,MD,MSPH •cold-, Executive Director and Chief Medical Officer re ..: p '< O Dedicated to protecting and Improving the health and environment of the people of Colorado * ., 4300 Cherry Creek Dr.S. Laboratory Services Division 'r e s / Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: Noble Energy, Inc—Timbro State LD16 Econode—Weld County Released To: The Greeley Tribune On: July 16,2014 Published: July 22,2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Noble Energy, Inc Facility: Timbro State LD16 Econode Oil and gas production and exploration facility NENE Section 16, T9N,R58W Weld County The proposed project or activity is as follows: Oil and gas exploration and production facility consisting of condensate tanks, produced water tanks, truck loadout, five 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 Ill.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section I1I.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 14WE0812 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: 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 STATE OF COLORADO 51 COQ COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT f" j AIR POLLUTION CONTROL DIVISION * *- TELEPHONE: (303) 692-3150 x,876+* CONSTRUCTION PERMIT PERMIT NO: 14WE081 2 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 Timbro State LD16 Econode, located in NENE Section 16, Township 9N, Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point Sixteen (16) above ground 500 bbl atmospheric condensate Condensate 001 storage tanks. Emissions from these tanks are controlled by tanks an enclosed flare. Six (6) 500 bbl atmospheric produced water storage tanks. PW 002 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. Equipment leaks (fugitive VOCs) from a natural gas Fugitives 004 exploration and production facility. One (1) GM, Model 5.7L, Serial Number 1M03234AH, natural gas-fired, naturally aspirated, 4SRB reciprocating VRU Comp 1 005 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. One (1) GM, Model 5.7L, Serial Number 1M06076AH, natural gas-fired, naturally aspirated, 4SRB reciprocating VRU Comp 2 006 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. AIRS ID: 123/9CB6/005 Page 1 of 25 NGEngine Version 2014-1 DCo do p e o Public PollutionHealthand ControlEnvironment Division Facility AIRS Description Equipment ID Point One (1) Cummins, Model G5.9, Serial Number 73480157, natural gas-fired, naturally aspirated, 4SRB reciprocating VRU Comp3 007 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) Caterpillar, Model G3508B, Serial Number RBK01266, natural gas-fired, turbo-charged, 4SLB GL Comp1 008 reciprocating internal combustion engine, site rated at 690 horsepower. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. . One (1) Caterpillar, Model G3306BA, Serial Number R6S01232, natural gas-fired, turbo-charged, 4SRB reciprocating internal combustion engine, site rated at 203 GL Comp2 009 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. These engines may be replaced with another engine in accordance with the temporary engine replacement provision or with another GM 5.7L, Cummins G5.9, Caterpillar G3508B or Caterpillare G3306BA 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 https://www.colorado.gov/pacific/cdphe/other-air-permittinq-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). AIRS ID: 123/9CB6/005 Page 2 of 25 9tCo do • p e o Public Health and Environment Air Pollution Control Division "� L. t . ., 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, Ill.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division aspart of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. The following information shall be provided to the Division within fifteen (15) days after issuance of permit. • manufacture date • construction date • order date • date of relocation into Colorado • manufacturer • model number • serial number This information shall be included with the Notice of Startup submitted for the equipment. (Reference: Regulation No. 3, Part B, III.E.) 6. 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 7. 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 Type Equipment ID Point NO VOC CO Condensate 001 --- 6.1 --- Point tanks PW 002 --- 3.3 --- Point TLO 003 --- 4.7 --- Point Fugitives 004 --- 78.9 --- Fugitives VRU Comp 1 005 2.4 0.8 4.1 Point VRU Comp 2 006 2.4 0.8 4.1 Point AIRS ID: 123/9CB6/005 Page 3 of 25 Co do i e o Public PollutionHealthand Control DivisionEnvironment VRU Comp3 007 2.3 0.8 3.9 Point GL Comp1 008 6.7 4.7 13.3 Point GL Comp2 009 2.0 1.4 3.9 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. 8. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit(Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID Condensate 001 Enclosed Flare VOC tanks PW 002 Enclosed Flare VOC TLO 003 Enclosed Flare VOC VRU Comp 1 005 Non-selective catalytic reduction (NSCR)system NOx, CO and air-fuel ratio controller VRU Comp 2 006 Non-selective catalytic reduction (NSCR)system NOx, CO and air-fuel ratio controller VRU Comp3 007 Non-selective catalytic reduction (NSCR)system NOx, CO and air-fuel ratio controller GL Comp1 008 Oxidation catalyst and air/fuel ratio controller VOC, CO, formaldehyde GL Comp2 009 Non-selective catalytic reduction (NSCR)system NOx, CO and air-fuel ratio controller 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) AIRS ID: 123/9CB6/005 Page 4 of 25 Co ado • p• e o Public Health and Environment t Air Pollution Control Division �, '?. a. Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID Condensate 001 Condensate throughput 900,000 BBUyr tanks PW 002 Produced water throughput 500,000 BBL/yr TLO 003 Condensate Loading 900,000 BBL/yr VRU Comp 1 005 Consumption of natural gas as a fuel 5.22 MMscf/yr VRU Comp 2 006 Consumption of natural gas as a fuel 5.22 MMscf/yr VRU Comp3 007 Consumption of natural gas as a fuel 4.39 MMscf/yr GL Comp1 008 Consumption of natural gas as a fuel 34.05 MMscf/yr GL Comp2 009 Consumption of natural gas as a fuel 11.31 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. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. 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.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. 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. 14. 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. AIRS ID: 123/9CB6/005 Page 5 of 25 D Co do p e o Public Health and Environment Air Pollution Control Division 15. 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. 16. 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. 17. 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) 18. 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 18 (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. 19. 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. 20. 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. AIRS ID: 123/9CB6/005 Page 6 of 25 .-us Co A do • p e o Public Health and Environment a Air Pollution Control Division ` f 21. 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. 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. 22. Points 005 and 006: 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 AIRS ID: 123/9C86/005 Page 7 of 25 D Co do p e o Public Health ti and Control nment 1■�_ Air Pollution Control Division 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 1 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. 23. Point 008: This equipment is subject to the control requirements for stationary and portable engines in the 8-hour ozone control area under Regulation No. 7, Section XVI.B.2. For lean burn reciprocating internal combustion engines, an oxidation catalyst shall be required. 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.) 25. 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. 26. Point 003: The owner or operator of a loadout at which vapor balancing is used 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 and return• these vapors to the stationary source storage tanks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. Use operating procedures to ensure that hydrocarbon liquid cannot be transferred unless the vapor collection equipment is in use. d. Operate all recovery and disposal equipment at a back pressure less than the pressure relief valve setting of transport vehicles. AIRS ID: 123/9CB6/005 Page 8 of 25 Co `do ■4p ' e o Public Health and Environment Air Pollution Control Division e. Inspect thief hatch seals annually for integrity and replace as necessary. Thief hatch covers shall be weighted and properly seated. f. 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. g. 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 27. Point 001: The owner or operator shall demonstrate compliance with Condition 14, 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.All) 28. 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. 29. Points 008 and 009: A source initial compliance test shall be conducted on emissions point 005 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. Volatile Organic Compounds using EPA approved methods. Formaldehyde Periodic Testing Requirements 30. Point 001: The owner or operator shall demonstrate compliance with Condition 14, 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.All) AIRS ID: 123/9CB6/005 Page 9 of 25 D Co do par C� ! e o Public HeaithPollution andControl Environment 1■p Air Division 31. 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. 32. Points 005, 006, 007, 008 and 009: 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 33. 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 sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Points 005, 006, 007, 008 and 009: Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 34. Federal regulatory program requirements (i.e. PSD or 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). AIRS ID: 123/9CB6/005 Page 10 of 25 Y Co do ms p e o Public Health and Environment Air Pollution Control Division GENERAL TERMS AND CONDITIONS 35. 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. 36. 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. 37. 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. 38. 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. 39. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality i 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. 40. 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. 41. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. AIRS ID: 123/9CB6/005 Page 11 of 25 Co do p e o PubD lic PollutionHealthand Control DivisionEnvironment 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, five reciprocating internal combustion engines and associated fugitives. Synthetic minor facility. • AIRS ID: 123/9C66/005 Page 12 of 25 pCo ikdo p e o Public Health and Environment Ill Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: http://www.colorado,00v/cs/Satellite?c=Document C&childdadename=CDPHE- Main°/02FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate(Ib/yr) (Ib/yr) Benzene 71432 A 1170 Yes 59 001 n-Hexane 110543 C 8100 Yes 405 ` Benzene 71432 A 3500 Yes 175 002 n-Hexane 110543 C 11000 Yes 550 Benzene 71432 A 1800 Yes 90 Toluene 108883 C 4500 Yes 225 003 Xylenes 1130207 C 900 Yes 45 Ethylbenzene 100414 C 2700 Yes 135 n-Hexane 110543 C 9900 Yes 495 Benzene 71432 A 1159 Yes 1159 Toluene 108883 C 2407 Yes 2407 004 Xylenes 1130207 C 587 Yes 587 Ethylbenzene 100414 C 1497 Yes 1497 n-Hexane 110543 C 5932 Yes 5932 Formaldehyde 50000 A 142 No 142 005 Methanol 67561 C 21 No 21 Acetaldehyde 75070 A 19 No 19 AIRS ID: 123/9CB6/005 Page 13 of 25 Co do p e o Public HealthPollution andContr EnolvironmentDivision 1■�_ Air 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 Formaldehyde 50000 A 142 No 142 Methanol 67561 C 21 No 21 Acetaldehyde 75070 A 19 No 19 006 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 Formaldehyde 50000 A 119 No 119 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 007 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 3,731 Yes 1,333 Acetaldehyde 75070 A 378 Yes 378 Acrolein 107028 A 232 No 232 008 Methanol 67561 C 113 No 113 n-Hexane 110543 C 50 No 50 Y Benzene 71432 A 20 No 20 Toluene 108883 C 18 No 18 Formaldehyde 50000 A 823 Yes 823 Methanol 67561 C 46 No 46 Acetaldehyde 75070 A 42 No 42 009 Acrolein 107028 A 39 No 39 Benzene 71432 A 24 No 24 , 1,3-Butadiene 106990 A 10 No 10 Toluene 108883 C 8 No 8 AIRS ID: 123/9CB6/005 Page 14 of 25 Co IIt do lip„ e o Public Health and Environment , Air Pollution Control Division 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/BBL Ib/BBL Source Condensate Condensate Throughput Throughput VOC 0.27 0.0135 EPA Tanks and WinSim EPA Tanks and 110543 n-Hexane 0.009 0.0005 WinSim 71432 Benzene 0.0013 0.00007 EPA Tanks and WinSim 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 CDPHE Memo 09- 02 110543 n-Hexane 0.022 0.0011 CDPHE Memo 09- 02 71432 Benzene 0.007 0.0004 CDPHE Memo 09- 02 Note: The controlled emissions factors for point 002 are based on the enclosed flare control efficiency of 95%. Point 003: Emission Factors - Emission Factors—Controlled Uncontrolled CAS Pollutant lb/BBL loaded Source Lb/BBL loaded Source VOC AP-42 AP-42 71432 Benzene 0.002 Engineering 0.0001 Engineering Calculation Calculation 108883 Toluene 0.005 Engineering 0.0003 Engineering Calculation Calculation 1130207 Xylenes 0.001 Engineering 0.0001 Engineering Calculation Calculation 100414 Ethylbenzene 0.003 Engineering 0.0002 Engineering Calculation Calculation 110543 n-Hexane 0.011 Engineering 0.0006 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 • S = 0.6 (Submerged loading: dedicated normal service) AIRS ID: 123/9CB6/005 Page 15 of 25 D Co do patt e o Public 1■�- Air PollutionHealihand Control DivisionEnvironment P (true vapor pressure)= 5.2 psia M (vapor molecular weight) = 66 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: Component Gas Service Heavy Oil Light Oil Water/Oil Service Connectors 2578 179 1133 247 Flanges 479 0 277 28 Open-ended Lines 3 0 0 0 Pump Seals 0 0 4 0 Valves 1599 69 997 184 Other* 367 40 146 57 VOC Content(wt. 0.307 1 1 1 fraction) Benzene Content(wt. 0.00095 0.0104 0.0104 0.0104 fraction) Toluene Content(wt. 0.00052 0.025 0.025 0.025 fraction) Ethylbenzene (wt. 0.00008 0.0062 0.0062 0.0062 fraction) Xylenes Content(wt. 0.00013 0.016 0.016 0.016 fraction) n-hexane Content(wt. 0.00393 0.0554 0.0554 0.0554 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump amis, 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 Point 005: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 1.4501 5.92 0.6859 2.80 AIRS ID: 123/9CB6/005 Page 16 of 25 104 Co do • p e o Public Health and Environment Air Pollution Control Division Emission Factors - Emission Factors— Uncontrol led Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr 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 1328 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 006: Emission Factors - Emission Factors— Uncontrolled 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 1328 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 Ib/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 AIRS ID: 123/9CB61005 Page 17 of 25 Co do p e o Public PollutionHealthand Control DivisionEnvironment Emission Factors - Emission Factors- Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr 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 1328 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 008: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 0.1473 0.50 0.2947 1.00 CO 0.9430 3.20 0.5894 2.00 VOC 0.4568 1.55 0.2063 0.70 50000 Formaldehyde 0.0825 0.28 0.0295 0.10 75070 Acetaldehyde 0.0084 0.03 0.0084 0.03 107028 Acrolein 0.0051 0.02 0.0051 0.02 67561 Methanol 0.0025 0.01 0.0025 0.01 110543 n-Hexane 0.0011 0.00 0.0011 0.00 71432 Benzene 0.0004 0.00 0.0004 0.00 108883 Toluene 0.0004 0.00 0.0004 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7481 Btu/hp-hr, a site-rated horsepower value of 690, and a fuel heat value of 1328 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer Point 009: Emission Factors- Emission Factors- Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 4.0333 15.45 0.2611 1.00 CO 4.0333 15.45 0.5221 2.00 VOC 0.1827 0.70 0.1827 0.70 50000 Formaldehyde 0.0548 0.21 0.0548 0.21 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 AIRS ID: 123/9CB6/005 Page 18 of 25 Co 1 d° ump e o Public Health and Environment I Air Pollution Control Division Emission Factors - Emission Factors— Uncontrol led Controlled CAS Pollutant Ib/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr 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 8445 Btu/hp-hr, a site-rated horsepower value of 203, and a fuel heat value of 1328 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer Manufacturer CO Manufacturer Manufacturer VOC Manufacturer Manufacturer 50000 Formaldehyde Manufacturer Manufacturer 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division. A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Points 007, 008 and 009: These engines are 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.qov/ttn/atw/area/fr18ia08.odf 8) Points 005, 006, 007, 008 and 009: 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.gov/ttn/atw/area/fr18ja08.pdf Additional information regarding area source standards can be found on the EPA website at: htto://www.epa.govittn/atw/area/arearules.html 9) This facility is classified as follows: Applicable Status Requirement Synthetic Minor/Major Source of: Operating Permit VOC, CO, n-hexane, total HAPS NANSR Synthetic Minor/Major Source of: VOC, CO MACT ZZZZ Area Source Requirements: Applicable 10) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ AIRS ID: 123/9CB6/005 Page 19 of 25 D Co do p e o Public 1M_ Air PollutionHealthand Control DivisionEnvironment Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60, Appendixes AppendixA—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 7777—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart XXXXXX 11) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: https://www.colorado.gov/pacific/cdphe/oil-and-gas-construction-perm it-self-certification AIRS ID: 123/9CB6/005 Page 20 of 25 -) Co Ado • p e o Public Health and Environment Air Pollution Control Division ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary" is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit(including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5) years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 123/9CB6/005 Page 21 of 25 DCo do p e o Public Health and Environment 1■y_ Air 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: http://www.colorado.qov/cs/Satellite/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: 123/9CB6/005 Page 22 of 25 Co A do ■ p e o Public Health and Environment Air 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. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9CB6/005 Page 23 of 25 Co do p e o Public PollutionHealthand Control DivisionEnvironment 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 A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9CB6/005 Page 24 of 25 6 ICoh do • p e o Public Health and Environment Air Pollution Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9CB6/005 Page 25 of 25 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc. Permit Number: 14WE0812 Timbro State LD 16 Econode Source Location: NENE Section 16, T9N, R58W Weld County (attainment) Point 001: condensate tanks Point 002: Truck Loadout produced water tanks Point 003: produced water tanks Point 004: Fugitive VOC leak emissions Equipment Description: Point 005: Reciprocating internal combustion engine Point 006: Reciprocating internal combustion engine Point 007: Reciprocating internal combustion engine Point 008: Reciprocating internal combustion engine Point 009: Reciprocating internal combustion engine AIRS ID: 123-9CB6 Date: July 9, 2014 Review Engineer: Stephanie Chaousy, PE 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 See Section 14 Information Request letter to the source? On what date was this application complete? April 25, 2014 Section 4—Source Description AIRS Point Equipment Description 001 Sixteen (16) above ground 500 bbl atmospheric condensate storage tanks. Emissions from these tanks are controlled by an enclosed flare. 002 Six (6) 500 bbl atmospheric produced water storage tanks. Emissions from these tanks are controlled by an enclosed flare. 003 Truck condensate loadout controlled by an enclosed flare. Page 1 004 Fugitive VOC leak emissions One(1)GM, Model 5.7L, Serial Number 1M03234AH, natural gas-fired, naturally 005 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. One(1) GM, Model 5.7L, Serial Number 1M06076AH, natural gas-fired, naturally 006 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. One(1) Cummins, Model G5.9, Serial Number 73480157, natural gas-fired, naturally 007 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) Caterpillar, Model G3508B, Serial Number RBK01266, natural gas-fired, turbo- 008 charged, 4SLB reciprocating internal combustion engine, site rated at 690 horsepower. This engine shall be equipped with an oxidation catalyst and air-fuel ratio control. This emission unit is used for natural gas compression. One(1) Caterpillar, Model G3306BA, Serial Number R6S01232, natural gas-fired, turbo- 009 charged, 4SRB reciprocating internal combustion engine, site rated at 203 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 Yes X No pollutant? If"yes", for what pollutant? PM10 CO 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 PK/110 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 Yes X No Regulation 7, Sections XII and XVII.C may apply) Point 002: Are"flash" emissions anticipated from these tanks? X Yes No 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, midstream or downstream site? Yes X No Point 002: Is this source claiming exempt status for this source based on the fraction of oil in the stored Yes water(less than 1% by volume crude oil on an average X No annual basis)? Point 002: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Page 2 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 Yes X 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 an average of two gas samples for WinSim and EPA tanks. See Section 14 for calculations. 002 CDPHE Produced Water Storage Tank Emission Factors; 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 2-4 005 NOx, CO and VOC: Manufacturer HAPS: AP-42 006 NOx, CO and VOC: Manufacturer HAPS: AP-42 007 NOx, CO and VOC: Manufacturer HAPS: AP-42 008 NOx, CO,VOC and formaldehyde: Manufacturer All other HAPS: AP-42 NOx, CO and formaldehyde: Manufacturer 009 VOC: NSPS JJJJ All other 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 001 900,000 BBL per year 002 500,000 BBL per year 003 900,000 BBL per year Page 3 Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2578 179 1133 247 004 Flanges 479 -- 277 28 Open-Ended Lines 3 --- --- — Pump Seals --- --- 4 --- Valves 1599 69 997 184 Other 367 40 146 57 005 5.22 MMscf/yr 006 5.22 MMscf/yr 007 4.39 MMscf/yr 008 34.05 MMscf/yr 009 11.31 MMscf/yr Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 900,000 BBL per year 002 500,000 BBL per year 003 900,000 BBL per year Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 2578 179 1133 247 004 Flanges 479 — 277 28 Open-Ended 3 — --- — Lines Pump Seals --- -- 4 — Valves 1599 69 997 184 Other 367 40 146 57 005 5.22 MMscf/yr 006 5.22 MMscf/yr 007 4.39 MMscf/yr 008 34.05 MMscf/yr J. 009 11.31 MMscf/yr Basis for Permitted Emissions(Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 900,000 BBL per year 002 500,000 BBL per year 003 900,000 BBL per year Equipment Type Gas Heavy Oil(or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2578 179 1133 247 004 Flanges 479 -- 277 28 Open-Ended Lines 3 --- --- --- Pump Seals — --- 4 --- Valves 1599 69 997 184 Other 367 40 146 57 005 5.22 MMscf/yr Page 4 006 5.22 MMscf/yr 007 4.39 MMscf/yr 008 34.05 MMscf/yr 009 11.31 MMscf/yr Does this facility have control devices? X Yes No %Reduction AIRS Point Process Control Device Description Granted 001 01 Flare 95 002 01 Enclosed flare 95 003 01 Flare 95 NOX: 52.7%; 005 01 NSCR and AFCR CO: 85.2% NOX: 52.7%; 006 01 NSCR and AFCR CO: 85.2% NOX: 91.2%; 007 01 NSCR and AFCR CO: 86.3%; VOC: 30%; CO: 37.5%; VOC: 54.8%; 008 01 Oxidation catalyst and AFCR formaldehyde: 64.3% CO: 87%; 008 a1 NSCR and AFCR NOx: 94%; Section 6—Emission Summary (tons per year) Point NO, VOC CO Single HAP Total HAP 001 --- 121.5 --- 4.1 (Hexane) 4.6 002 --- 65.5 --- 5.5 (n-hexane) 7.3 003 --- 93.2 -- 5.0 (n-hexane) 10.8 004 --- 78.9 -- 3.0(n-hexane) 5.8 005 5.0 0.9 27.5 0'1 0.1 PTE: (formaldehyde) 0.1 k 006 5.0 0.9 27.5 0.1 (formaldehyde) 067 9.3 0.8 11.9 0.06 0.08 (formaldehyde) 1.9 008 3.3 10.3 21.3 2.2 (formaldehyde)0.4 009 30.3 1.4 30.3 0.5 (formaldehyde)de) 001 --- 121.5 --- 4.1 (Hexane) 4.6 002 --- 65.5 --- 5.5 (n-hexane) 7.3 003 --- -93.2 --- 5.0 (n-hexane) 10.8 Uncontrolled point source emission rate:. 004 --- 78.9 --- 3.0 (n-hexane) 5.8 0.1 005 5.0 0.9 27.5 (formaldehyde)0.1 0.1 006 5.0 0.9 27.5 (formaldehyde) 0.1 Page 5 0.007 9.3 0.8 11.9 (formald0ehyde) 0.08 1.9 008 3.3 10.3 21.3 2.2 (formaldehyde)0.4 009 30.3 1.4 30.3 (formaldehyde) 0.5 001 - 6.1 --- 0.2 (Hexane) 0.23 002 - 3.3 --- 0.3 (n-hexane) 0.4 003 - 4.7 - 0.25 (n-hexane) 0.5 004 -- 78.9^ - 3.0 (n-hexane) 5.8 0.1 Controlled point 005 2.4 0.9 4.1 (formaldehyde) 0.1 source emission rate: 006 2.4 0.9 4.1 0.1 0.1 (formaldehyde) 007 2.3 0.8 3.9 (formald0ehyde) 0.08 0.7 008 6.7 4.7 13.3 1.0 (formaldehyde)0.4 009 2.0 1.4 3.9 0.5 (formaldehyde) Total APEN Reported 15.8 22.8 29.3 3.8 (n-hexane) 8.7 emissions: ^Fugitive emissions not included when determining facility status(true minor, synthetic minor, major) Section 7—Non-Criteria/ Hazardous Air Pollutants Uncontrolled are the Controlled Emission Pollutant CAS# BIN Emission Rate emissions (lbyr) reportable? Rate(lbhr) Point 001 Benzene 71432 A 1170 Yes 59 n-Hexane 110543 C 8100 Yes 405 Point 002 Benzene 71432 A 3500 Yes 175 n-Hexane 110543 C 11000 Yes 550 Point 003 Benzene 71432 A 1800 Yes 90 Toluene 108883 C 4500 Yes 225 Xylenes 1130207 C 900 Yes 45 Ethylbenzene 100414 C 2700 Yes 135 n-Hexane 110543 C 9900 Yes 495 2,2,4-TMP 540841 C 1800 Yes 90 Point 004 Benzene 71432 A 1159 Yes 1159 Toluene 108883 C 2407 Yes 2407 Xylenes 1130207 C 587 Yes 587 Ethylbenzene 100414 C 1497 Yes 1497 Page 6 n-Hexane 110543 C 5932 Yes 5932 Points 005 and 006 each Formaldehyde 50000 A 142 No 142 Acetaldehyde 75070 A 19 No 19 Acrolein 107028 A 18 No 18 Benzene 71432 A 11 No 11 Point 007 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 008 Formaldehyde 50000 A 3731 Yes 1333 Acetaldehyde 75070 A 378 Yes 378 Acrolein 107028 A 232 No 232 Benzene 71432 A 20 No 20 Point 009 Formaldehyde 50000 A 823 Yes 823 Acetaldehyde 75070 A 42 No 42 Acrolein 107028 A 39 No 39 Benzene 71432 A 24 No 24 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? r If'yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001 01 VOC, Regulation No. 7 Section XVII.All EPA Method 22 HAPS 003 01 VOC, State requirement only Hard component HAPS count 008 01 VOC• CO Regulation No. 3, Part B., Section III.G.3 Stack test 009 01 VOC• CO Regulation No. 3, Part B., Section III.G.3 Stack test 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 MACT Page 7 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 is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60,Appendix A(July, 001-009 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. 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 001-009 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: 001-009 each individual emission point in an attainment area with uncontrolled actual emissions of two tons per year or more of any individual criteria pollutant (pollutants are not summed)for which the area is attainment. (Applicant is required to file an APEN since emissions exceed 2 tons per year VOC) Part B—Construction Permit Exemptions 001-009 Applicant is not required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 5.0 TPY threshold(Reg. 3, Part B, Section Il.D.3.a) Page 8 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 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)?Yes Is this source subject to NSPS Kb? No WHY? These tanks are all prior to custody transfer, therefore, not subject to this subpart. 002, 005, None 006 003 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? This source is not located at a natural gas processing plant. Therefore, it does not meet the criteria of this subpart. NSPS JJJJ: The date of construction is the date it was ordered or reconstructed/modified. 007, 008, These engines were manufactured after the 7/1/2008 effective date and are therefore 009 subject to NSPS JJJJ. All three engines must meet 1.0 g/hp-hr for NOx, 2.0 g/hp-hr for CO and 0.7 g/hp-hr for VOC. Page 9 Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS (Applicant is not subject to the emission control requirements for condensate tanks 001 since it is located 1n an 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.) 002 None 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. Section XII.G: If facility is a natural gas processing plant located in non-attainment 004 area,then subject to Section XII.G. This facility is not a natural gas processing plant, therefore, not subject to this subpart. 005, 006 Since these engines are not subject to NSPS JJJJ,they are subject to Regulation 7 engine requirements. 007, 008, Because these engines are subject to NSPS JJJJ, they are not subject to Regulation 009 7 requirements. 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, 008, location, therefore, the engines are new sources of MACT 777Z. 009 Section 13—Aerometric Information Retrieval System Coding Information Emission Emission Pollutant/ Fugitive Factor Control Point Process Process Description Factor CAS# (Y/N) ('70) Source 6.3243 EPA Tanks lb/1000 gal V0C No &WinSim 95 E&P Condensate 900,000 0.03 Benzene/ EPA Tanks 01 Storage Tanks BBUyr lb/1000 gal 71432 No &WinSim 95 001 0.2169 n-Hexane/ No EPA Tanks 95 lb/1000 gal 110543 &WinSim SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses Process Process/ Emission Pollutant/ Fugitive Emission Control Point Process Description throughput Factor CAS# (y/N) Factor ("70) Limit Source 6.2381 CDPHE PS lb/1000 gal V0C No Memo 09-02 95 01 Produced Water 500,000 0.1667 Benzene No CDPHE PS 95 002 Storage Tanks BBL/yr lb/1000 gal Memo 09-02 0.5238 n-Hexane No CDPHE PS 95 lb/1000 gal Memo 09-02 SCC 40400315— Fixed Roof Tank, Produced Water,working+breathing+flashing losses 4.93 V0C No AP-42 95 lb/1,000 gal 003 01 Truck Condensate 900,000 0.0476 Benzene/ No Engineering 95 Loadout BBUyr lb/1000 gal 71432 Calculation 0.119 Toluene/ Engineering lb/1000 gal 108883 No Calculation 95 Page 10 0.0714 Xylenes/ Engineering lb/1000 gal 1130207 No Calculation 95 0.0238 Ethylbenzen Engineering lb/1000 gal e/ 100414 No Calculation 95 0.2619 n-Hexane/ Engineering lb/1000 gal 110543 No Calculation 95 0.0476 2,2,4-TMP Engineering lb/1000 gal /540841 No Calculation 95 SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 01 Fugitive VOC Leak VOC Yes EPA-453/R-95-017, NA 004 Emissions Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) 1.0 g/hp-hr VOC No Conservative 0 005 014SRB Engine 5.22 5.92 g/hp- NOx No Manufacturer 52.7 and mmscf/yr hr 006 32.4 g/hp- CO No Manufacturer 85.2 each hr SCC 20200253—4-cycle rich burn 1.0 g/hp-hr VOC No Conservative 0 01 4SRB Engine 4.39 11.41 NOx No Manufacturer 75.5 007 mmscf/yr 9/hp-hr 14.64 CO No Manufacturer 67.2 g/hp-hr SCC 20200253—4-cycle rich burn 1.55 g/hp- VOC No Manufacturer 54.8 hr 0.5 g/hp-hr NOx No Manufacturer NA* 01 4SLB Engine 34.05 008 mmscf/yr 3.2 g/hp-hr CO No Manufacturer 37.5 0.28 g/hp- Formaldehy No Manufacturer 64.3 hr de/50000 SCC 20200254—4-cycle lean burn *Controlled emissions are at 1.0 g/hp-hr(per NSPS JJJJ) 0.7 g/hp-hr VOC No NSPS JJJJ 0 01 4SRB Engine 11.31 15.45 NOx No Manufacturer 94 • 009 mmscf/yr g/hp-hr 15.45 CO No Manufacturer 87 g/hp-hr SCC 20200253—4-cycle rich burn Page 11 Section 14—Miscellaneous Application Notes AIRS Point 001 Condensate Storage Tanks A permit will be issued because the uncontrolled VOC emissions are greater than 5 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 March 18, 2014 (within a year of application submittal). Uncontrolled emission factors with 600,000 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 85.07 34.48 0.189 0.07662 0.2656 6.3243 Benzene 0.2716 0.295 0.0006 0.000656 0.0013 0.0300 n-hexane 2.4076 1.69 0.00535 0.00376 0.0091 0.2169 I emailed the operator on 7/10/14 regarding the O&M plan. The plan was marked with"permitted facility emissions less than 80 TPY VOC"but when I added up the permitted VOCs it was over 80 TPY. Operator wrote back on 7/10/14 requesting to redline the O&M. 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, 62381 0.1667 . 0.5238 €kulglas, Jefferson Latimer arid Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado 6.2381 0.1667 0.5238 Page 12 AIRS Point 003 Truck Condensate Loadout Units Basis S 0.6 Submerged loading: dedicated normal service P 5.2 Psia Based on EPA TANKs run M 66 Lb/lb-mole Based on EPA TANKs run T 520 Deg R Based on source's knowledge of bulk liquid temperature L 4.93 Lb/10^3 gal This value is used to calculate annual emissions 0.207 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 [lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] L 4.931b/10^3 gal 2.07E-01 lb/bbl Annual requested Throughput 37800000ga1/yr Annual requested VOC emissions 186511 lb/yr 93.2tpy HAPS were calculated from the extended NGL analysis for well LD-16-67HN. Uncontrolled HAP emissions and emission factors are: Benzene= 1800/900000 = 0.002 lb/bbl * 1000/42 = 0.0476 lb/1000 gal Toluene= 4500/900000 = 0.005 lb/bbl * 1000/42 = 0.1190 lb/1000 gal Ethylbenzene= 900/900000 = 0.001 lb/bbl * 1000/42 = 0.0238 lb/1000 gal Xylenes= 2700/900000 = 0.003 lb/bbl * 1000/42 = 0.0714 lb/1000 gal n-hexane= 9900/900000 = 0.011 lb/bbl * 1000/42 = 0.2619 lb/1000 gal 2,2,4-TMP = 1800/900000 = 0.002 lb/bbl * 1000/42 = 0.0476 lb/1000 gal AIRS Point 004 Fugitive VOC Leak Emissions A permit will be issued because the uncontrolled VOC emissions are greater than 5 TPY (permit threshold). I emailed the operator on (7/9/2014): I believe gas valves n-hexane isn't correct. I calculated a much higher number of 546.1 lb/yr. I heard back from the operator 7/10/14: I have attached a revised data sheet I had the wrong weight percent on my spreadsheet, so all of the n-hexane gas vapor emissions are wrong. Please let me know if you need a revised APEN. AIRS Point 005 4SRB A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY (permit p threshold). AIRS Point 006 4SRB A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). Page 13 AIRS Point 007 4SRB A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). I emailed the operator on (7/9/2014): it is subject to NSPS JJJJ, however, the control is not meeting 1.0 g/hp-hr NOx, 2.0 g/hp-hr CO and 0.7 g/hp-hr. I believe this should be revised. I believe the controlled emissions should be 0.8 TPY NOx, 0.6 TPY VOC and 1.6 TPY CO. I heard back from the operator on 7/10/14: The Cummins engine is a G5.9, 84 hp engine. It's my understanding that the JJJJ emission standard for engines 25 >hp < 100 is 2.8 g/hp-hr Nox, and 4.8 g/hp-hr CO. It would be same as the two GM 5.7L engines. Please let me know. The engine has NSCR, so it can easily meet the 1.0, 2.0, 0.7 limits. I have attached the part of the reg. (Table 3) that lists the standards for this size engine. The 4.8 g/hp-hr is for HC+Nox, but footnote B says you may assume that HC emissions are equal to zero. This information is in the Federal Register,Vol. 73, No. 13,Table 3. AIRS Point 008 4SLB A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). AIRS Point 009 4SRB A permit will be issued because the uncontrolled CO emissions are greater than 10 TPY(permit threshold). Page 14 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY wit 2520]4 Current Status(Check all that apply) Reason for APEN Submittal(Check all that apply) -- AIRSID#': 12 BO 3- IC6" °I O APEN update only4 r, ® New or previously unreported battery ❑ Modification to existing source '' ❑ Previously grandfathered battery" O Registration for coverage under general permit no.GPOI and ® Synthetic minor facility cancellation request for individual permit6: ❑ Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit ❑ Registered under general permit no. GPOI ❑ Administrative permit amendment' ❑ Permitted under individual permit: /4{WE;06(7 ❑ Other: For individual permit applications,check if you wants: ❑A copy of the preliminary analysis conducted by the Division ®To review a draft of the permit prior to issuance Company Name: Noble Energy,Inc OGCC Operator#: 100322 Mailing Address10: 1625 Broadway Suite 2200 mputney@nobleenergyinc City: Denver State: CO Zip: 80202 E-mail: .com Contact Name: Mike Putney Phone: (303)228-4385 Fax: (303)228-4286 Tank Battery Name": Timbro State LD 16 Econode Number of tanks: 16 Location"(QQ Sec.Twp. Range.): NENE SEC16 T9N R58W County: Weld Total tank capacity[bbl]: 8,000 Calendar year for which"Actual"data applies13: 2014 Year(s)tank(s)were placed in service": 2014 Control Descriptions: FLARE(Vapor Combustors) Control Efficiency"b: 95% Condensate Throughput"[bbl/year] Requested": 900,000 Maximum for PTE calculation": 900,000 Actual20: While Controls Operational21 Other equipment at facility22: Comments: Estimated emissions at throughputs listed above. Use N/A for requested throughput/emission values unless requesting an individual permit ❑ Check if the Division is to calculate emissions. ®Check if site-specific emission factors provided to calculate emissions23. Emission Factor Battery Requested EmissionsIs Actual Emissions"° Pollutant"4 [lb/bbl] PTE25 Uncontrolled26 Controlled20 Uncontrolled�s Controlled" VOC[tons/year] 0.27 121.5 121.5 6.08 NOx[tons/year] CO[tons/year] Benzene[lbs/year] 0.0013 1,170 1,170 58.5 n-Hexane[lbs/year] 0.009 8,100 8,100 405 Wells serviced by this tank or tank battery2s API#: 05-123-37490 Name: Timbro State LD16-67HN ®Newly Reported Well API#: 05-123-37549 Name: Timbro State LD16-67-1HN ®Newly Reported Well API#: 05-123-37550 Name: Timbro State LD16-66HN ®Newly Reported Well API#: 05-123-37548 Name: Timbro State LDI6-66-1HN ®Newly Reported Well API#: 05-123-37489 Name Timbro State LD16-65HN is Newly Reported Well API#: 05-123-37493 Name: Timbro State LD16-68-1HN ®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 knn ledge and belief. If this is.a registration for coverage under general permit GPI,I further certify that this source is and will be operated tin co Hance 11 epq ondition of ral permit GPI. / 1 r April 24,2014 Sign e of Legally Authorized Person(not a vendor or consultant) Date Dan Kelly VP-DJ Basin Operations Type or Print Name of Person Signing Above Official Title i Submit this form,along with$152.90 for each Colorado Department of Public Health and Environment.. a For information call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-B1 j 094 7 f] (303)692-3150 $250 General Permit fee for each new GP 4300 Cherry Creek Drive South P I registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 TIMBRO STATE LD16 APEN COND TANK BATTERY o ° eJ a s _ E c a E o c ❑ O ° P. CC V a C v N N N .r-. 01 P- 7 ° ° O O. ° a Cl , V L N L G O O O _ L GG O ate+ m e a E .a ,n y `o K 9 PU. 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