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Home My WebLink About20141659.tiff STATE OF COLORADO John W.Hickenlooper,Governor oe cot Larry Wolk, MD,MSPH , O,n 37 Executive Director and Chief Medical Officer Fe vo CI Dedicated:0 protecting and improving the health and environment of he people of Colorado ` 91 4300 Cherry Creek Dr.S. Laboratory Services Division x,rav6 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.govicdphe and Environment Weld County - Clerk to the Board 1150 O St PO Box 758 Greeley, CO 80632 RECEIVED May 28,2014 MAY 3 0 2014 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On June 1,2014,the Air Pollution Control Division will publish a public notice for Noble Energy, Inc.— Holman 815-65HNM, 66HN & Cockroft B11-62-INN, 69-1HNM, 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, Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure TtA- i.c 2 OP,: Pt(MM) N t.I 98) )9u)CM, ,iM) • - q- 1� 5730 i 2014-1659 l� STATE OF COLORADO John W.Hickenlooper, Governor Larry Wolk,MD, MSPH p/v Executive Director and Cnief Medical Officer e/ t.t"\ Cl Dedicated to protecting and mproving the health and environment of the people of Colorado 4300 Cherry Creek Dr. S. Laboratory Services Division R76 ., rr 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.govicdphe and Environment Website Title: Noble Energy. Inc.— I lolntan B15-65HNM, 661 IN &Cockroft B 1 1-62-I[IN. 69-1 HNM — Weld County Released To: The Greeley Tribune On: May 28, 2014 Published: June 1,2014 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 tbllowing source of air pollution: Applicant: Noble Energy, Inc. Facility: Holman B 15-65HNM. 661 IN & Cockroft B 1 1-62-I HN. 69-1 HNM 'aellpad SL'.NW Section 14, TSN, R64W Weld County The proposed project or activity is as follows: The applicant proposes a new wellpad with fourteen(14) 300 BBL condensate tanks. four(4) 300 BBL produced water tanks. loadout for the condensate tanks, two 4 stroke rich bur engines. and associated fugitives. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section II I.C clue to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3. Part B. Section I II.C.I.a (25 tpy in a non-attainment area and/or 50 tpv in an attainment area) • the source is requesting a federallc 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 14WE0644 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 ww‘v.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: Rebecca Vasil Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B 1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us 4 ArrA4 AA 4: 3i C I _ g 44i z;; t j -g `'r STATE OF COLORADO ,I } - y gng t1 R ) OF-`,p2A� COLORADO DEPARTMENT OF PI Q IC HEALTH .AND ENVIRONMENT FT'4/714�1 AIR POLLUTION CONTROL DIVISION ' ° : TELEPHONE: im'(303)692-3150 v . 1876• CONSTRUCTION PERMIT PERMIT NO: 14WE0644 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 Holman B15-65HNM, 66HN & Cockroft B11-62-1HN, 69-1HNM, located in the SENW Section 14 T5N R64W, in Weld County; Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Fourteen (14) 300 BBL fixed roof storage tanks used to store TANKS 001 condensate. Emissions from these tanks are controlled by an enclosed flare. Four (4) 300 BBL fixed roof storage tanks used to store PW 002 produced water. Emissions from these tanks are controlled by an enclosed flare. TLO 003 Truck loadout of condensate. Emissions from the loadout are not controlled. Fugitives 004 Equipment leaks (fugitive VOCs) from a natural gas exploration and production facility. One (1) Cummins, Model G5.9, Serial Number 2LB016989, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP1 005 internal combustion engine, site rated at 84 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control This emission unit is used for natural gas compression. One (1) Cummins, Model G5.9, Serial Number 2LB016933, natural gas-fired, naturally aspirated, 4SRB reciprocating COMP 2 006 internal combustion engine, site rated at 84 horsepower. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control This emission unit is used for natural gas compression. AIRS ID: 123/9CA4 Page 1 of 23 Fugitive SM/M Version 2012-2 olor.. ". Depa en . - .li Health and Environment a •it Pollution Control Division The engines mays, ,s:, =cer . i e a . -*; cord '=P-with the temporary engine replacement provision or with another Cummins G5.9 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. 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 www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference: Regulation No. 3, Part B, Section III.E.) 5. Point 005, Point 006: 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.) AIRS ID: 123/9CA4 Page 2 of 23 tar s-olora Depa enr f PtlidHealth and Environment Zir Pollution Control Division • , tl �I. 6. The operator tin e . al maw n let sued 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 Pounds per Month Equipment Point Emission Type ID NOx VOC CO TANKS 001 --- 10.2 --- Point PW 002 --- 2.62 --- Point TLO 003 --- 48.4 --- Point Fugitives 004 --- 45.2 --- Fugitive COMP1 005 2.3 0.8 3.9 Point COMP2 006 2.3 0.8 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 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 emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 8 Point 004: The operator shall calculate actual emissions from this emissions point based on representative component counts for the facility with the most recent gas and liquids analyses, as required in the Compliance Testing and Sampling section of this permit. The operator shall maintain records of the results of component counts and sampling events used to calculate actual emissions and the dates that these counts and events were completed. These records shall be provided to the Division upon request. AIRS ID: 123/9CA4 Page 3 of 23 olor. Depa en : ---7.li 'Health and Environment it Pollution Control Division 9 The emission ,"4-.. : " th . e¶ „sh-.,7a: - .,r_ated . ai$ aintained 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 TANKS 001 Enclosed Flare VOC, HAPs PW 002 Enclosed Flare VOC, HAPs COMP1 005 Oxidation catalyst and air/fuel ratio controller NOx and CO COMP2 006 Oxidation catalyst and air/fuel ratio controller NOx and CO PROCESS LIMITATIONS AND RECORDS 1. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility nnu Equipment Po. Process Parameter ALimitl ID TANKS 001 Condensate throughput 400,000 BBUyr PW 002 Produced water throughput 400,000 BBUyr TLO 003 Condensate Loading 400,000 BBUyr COMP1 005 Consumption of natural gas as a fuel 4.55 MMscf/yr COMP2 006 Consumption of natural gas as a fuel 4.55 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. Point 001, Point 002, Point 005, Point 006: 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 AIRS ID: 123/9CA4 Page 4 of 23 St aolora 1Depar nenr of P blic'Health and Environment ri it Pollution Control Division 1111 equipment visernissious sha`Itexceat - opacitybxr 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. 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 emission control requirements. These requirements include, but are not limited to: Section XVII.C. - Emission reduction from condensate storage tanks at oil and gas exploration and production operations, natural gas compressor stations, natural gas drip stations and natural gas processing plants. XVII.C.1. 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. XVII.C.3. Monitoring: The owner or operator of any condensate storage tank that is required to control volatile organic compound emissions pursuant to this section XVII.C. shall visually inspect or monitor the Air Pollution Control Equipment to ensure that it is operating at least as often as condensate is loaded out from the tank, unless a more frequent inspection or monitoring schedule is followed. In addition, if a flare or other combustion device is used, the owner or operator shall visually inspect the device for visible emissions at least as often as condensate is loaded out from the tank. XVII.C.4. Recordkeeping: The owner or operator of each condensate storage tank shall maintain the following records for a period of five years: AIRS ID: 123/9CA4 Page 5 of 23 ;r olor Depa - en P .li `Health and Environment •it Pollution Control Division XVII. ,.. ,. " th ' .':•r.,= pr F .$= romt - _, k. XVII.C.4.b For any condensate storage tank required to be controlled pursuant to this section XVII.C., the date, time and duration of any period where the air pollution control equipment is not operating. The duration of a period of non-operation shall be from the time that the air pollution control equipment was last observed to be operating until the time the equipment recommences operation. XVII.C.4.c. For tanks where a flare or other combustion device is being used, the date and time of any instances where visible emissions are observed from the device. 17. Point 002: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance. This source shall meet the requirements to apply RACT and reduce emissions by installing and operating an enclosed flare. (Reference: Regulation No. 3, Part B, III.D.2.a). 18. Point 003: This source is located in an ozone non-attainment or attainment- maintenance area and is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation Number 3, Part B, III.D.2.a. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) 19. Point 003: The owner or operator shall follow loading procedures that minimize the leakage of VOCs to the atmosphere including, but not limited to (Reference: Regulation 3, Part B, III.E): a. Hoses, couplings, and valves shall be maintained to prevent dripping, leaking, or other liquid or vapor loss during loading and unloading. 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 19 (a) and (b) above. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 20. Point 003: All hydrocarbon liquid loading operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. 21. Point 004: This source is subject to Regulation No. 7, Section XII.C General Provisions (State only enforceable). All condensate collection, storage, processing and handling operations, regardless of size, shall be designed, operated and maintained so as to minimize leakage of volatile organic compounds to the atmosphere to the maximum extent practicable. The operator shall comply with all applicable requirements of Section XII. 22. Point 004: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B. shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance (Reference: Regulation No. 3, Part B, AIRS ID: 123/9CA4 Page 6 of 23 sx :1: v gaff of g ! OolorainDepartmenbtdf P. licf)Health and Environment g it Pollution Control Division bfg gu:III.D.2.a). Thisri rq me€t' . a MAO =...-a{ sate 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. 23. Point 005, Point 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 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 AIRS ID: 123/9CA4 Page 7 of 23 m.,, olor. , Depa . en : I,di Health and Environment tux, a n, R a,x; it Pollution Control Division r <100HP Any 1 A N/A N/A ≥100HP and January 1, 2008 2.0 4.0 1.0 <500HP January 1, 2011 1.0 2.0 0.7 ≥500HP July 1, 2007 2.0 4.0 1.0 July 1, 2010 1.0 2.0 0.7 Maximum engine horsepower is the nameplate rating of the engine and does not account for deration. Note: Per Regulation No. 7, Section XVII.B.4, internal combustion engines that are subject to an emission standard or an emissions control requirement in a federal maximum achievable control technology ("MACT") standard under 40 CFR Part 63, a Best Available Control Technology ("BACT") limit, or a New Source Performance Standard under 40 CFR Part 60 are not subject to this Section XVII. OPERATING & MAINTENANCE REQUIREMENTS 24. Point 001, Point 004, point 005, Point 006: 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 002: Flares shall be enclosed, have no visible emissions, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare, or by other convenient means approved by the Division, determine whether the flare is operating properly. 26. Point 002: If a control device is used to comply with the emission limits of this permit, the following conditions must be met: a. Leakage of VOCs to the atmosphere must be minimized as follows: (i) Thief hatch seals shall be inspected for integrity annually and replaced as necessary. Thief hatch covers shall be weighted and properly seated. (ii) Pressure relief valves (PRV) shall be inspected for proper operation annually and replaced as necessary. PRVs shall be set to release at a pressure that will ensure flashing, working and breathing losses are routed to the control device under normal operating conditions. (iii) Annual inspections of thief hatches and PRV shall be documented with an indication of status, a description of any problems found, and their corrective action. 27. Point 002: Control devices shall be adequately designed, and operated and maintained according to manufacturer specifications to achieve a control efficiency of at least 95%, and to handle reasonably foreseeable fluctuations in emissions of VOCs. Fluctuations in emissions that occur when the separator dumps into the tank are reasonably foreseeable. 28. Point 002: The owner or operator shall monitor and document the proper operation of the control device. Time intervals between monitoring shall not exceed 14 days. AIRS ID: 123/9CA4 Page 8 of 23 Folorai ,Depar enz"MMP nblicrHealth and Environment .f , "ger t i,iAir Pollution Control Division {I Indications of:ittipraper opefatiotll forma flare Ancltide, but.araanot limited to, absence of pilot light, malfunction of electronic ignition, and/or presence of smoke. A check box is suitable for recording proper operation. Improper operation of a control device shall be further documented with a description of the problem and its corrective action, the date range the control was inoperable, and the produced water production through the battery during the downtime. If the owner or operator cannot document the date that the control equipment became inoperable then downtime shall be assumed to have started directly after the last documented monitoring event. During control device downtime, emissions shall be considered to be uncontrolled. 29. Point 003: This source is not required to follow a Division-approved operating and maintenance plan. COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 30. Point 001, Point 002: The owner or operator shall demonstrate compliance with Condition 11, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.AII) 31. 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. Periodic Testing Requirements 32. Point 001: The owner or operator shall demonstrate compliance with Condition 11, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7 Section XVII.AII) 33. Point 004: On an annual basis. the owner or operator shall complete an extended gas analysis of gas samples and an extended natural gas liquids analysis of liquids that are representative of volatile organic compounds (VOC) and hazardous air pollutants (HAP) that may be released as fugitive emissions. This extended gas and liquids analyses shall be used in the compliance demonstration as required in the Emission Limits and Records section of this permit. 34 Point 005, Point 006: 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 35 A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) AIRS ID: 123/9CA4 Page 9 of 23 f olor 1S Depa 7, en t P ).li Health and Environment it Pollution Control Division a. Annua<. ril 5 n r - ._ -nt in - in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOx) in ozone nonattainment areas emitting less than 100 tons of VOC or NO, per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or 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. Point 005, Point 006: 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. 36. 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). GENERAL TERMS AND CONDITIONS: 37. 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. 38. 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 AIRS ID: 123/9CA4 Page 10 of 23 rte t;CoIora,4 4Depar nenPof P ablic Health and Environment `t S Li ddAr Pollution Control Division III.G. Final authorization aatnnot-be.granted„uatitthe opetation 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. 39. 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. 40. 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. 41. Each and every condition of this permit is a material part hereof and is not severable. Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self-certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express term or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the owner or operator, or the Division revokes a permit, the owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 42. 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. 43. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties). C R.S. By: Rebecca Vasil Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance , Issued to Noble Energy AIRS ID: 123/9CA4 Page 11 of 23 zxt II ! olor Depa en .li Health and Environment r Pollution Control Division Notes to Permit Holder :�.. - me o .e an-=' �' 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference. Regulation No. 3, Part A, Section VI.B.) 2) The emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: http://www.colorado.gov/cs/Satellite?c=Document C&childpagename=CDPHE- Main%2FDocument 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 Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS# BIN (Ib/yr) reportable? (lb/yr) Benzene 71432 A 1,560 Yes 78 001 Hexane 110543 C 13,600 Yes 680 Uncontrolled Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS # BIN (Ib/yr) reportable? (Ib/yr) Benzene 71432 A 2,800 Yes 140 002 - Hexane 110543 C 8,800 Yes 440 Uncontrolled Controlled Emission Are the Emission AIRS Rate emissions Rate Point ; Pollutant CAS # BIN (Ib/yr) reportable? (Ib/yr) Benzene 71432 A 800 Yes 800 Toluene 108883 C 3,200 Yes 3,200 003 Xylenes 1330207 C 2,400 Yes 2,400 n-Hexane 110543 C i 6,800 Yes 6,800 224-TMP 540841 C I 400 Yes 400 AIRS ID: 123/9CA4 Page 12 of 23 ii J t� A-x4-1olora Deparix'nen of PI`bic'Health and Environment a Ir t4 Air Pollution Control Division n ,,, Uncontrolled ; Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS # BIN (Ib/yr) reportable? (Ib/yr) Benzene I 71432 I A 623 Yes 623 E Toluene 108883 C I 2,132 Yes 2132 004 Ethylbenzene 100414 C 176 No 176 Xylenes 1330207 C 1752 Yes 1752 - n-Hexane 110543 C 4.327 Yes 4327 Uncontrolled ------I Are the l Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (Ib/yr) reportable? Rate(Ib/yr) Formaldehyde 50000 A 119 No 119 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 005 Acrolein 107028 A 15 No I 15 Benzene 71432 A 9 No 9 1,3-Butadiene 106990 j A 4 No 4 Toluene 108883 C 3 No 3 Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Point Pollutant CAS # BIN (Ib/yr) reportable? Rate(Ib/yr) Formaldehyde 50000 A 119 No 119 Methanol 67561 C 18 No 18 Acetaldehyde 75070 A 16 No 16 006 Acrolein 107028 A 15 No 15 Benzene 71432 A I 9 No 9 1.3-Butadiene 106990 A I 4 No 4 Toluene 108883 C l 3 No 3 AIRS ID: 123/9CA4 Page 13 of 23 1r olor = Depa en . P .li `Health and Environment it 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 lb/BBL Source Condensate Condensate Throughput Throughput VOC 1.02 0.051 Source 110543 n-Hexane 0.034 0.0017 Source 71432 Benzene 0.0039 0.000195 Source Note: The controlled emissions factors for point 001 are based on the flare control efficiency of 95%. Point 002: Emission Factors Emission Factors Uncontrolled Controlled CAS # Pollutant lb/BBL lb/BBL Source Condensate Condensate Throughput Throughput VOC 0.262 0.0131 CDPHE 110543 n-Hexane 0.022 0.0011 CDPHE 71432 Benzene 0.007 0.00035 CDPHE Note: The controlled emissions factors for point 002 are based on the flare control efficiency of 95%. Point 003: Emission Factors - Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.242 AP-42 71432 Benzene 0.002 Source 108883 Toluene 0.009 Source 1330207 _ Xylenes 0.006 Source 110543 n-Hexane 0.018 Source 540841 224-TMP 0.001 Source The uncontrolled VOC emission factor was calculated using AP-42, Chapter 5.2, Equation 1 (version 1/95) using the following values: L = 12.46*S*P*M/T S = 0.6 (Submerged loading: dedicated normal service) P (true vapor pressure) =6.14 psia M (vapor molecular weight) =64 Ib/Ib-mol T (temperature of liquid loaded) = 510 '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. AIRS ID: 123/9CA4 Page 14 of 23 4.15,.‘„, £: >;r s \ :v olora. Depar finer of P , lic'Health and Environment F „,s Air Pollution Control Division _ n . Point 004: , .. . . , •-. Water/Oil Component Gas Service Heavy Oil Light Oil Service Connectors 2680 0 687 342 Flanges J 401 0 i 112 22 Open-ended Lines 1 31 0 0 0 Pump Seals 0 0 2 0 Valves 1041 0 677 147 _ Other* 370 _ 0 63 47 VOC Content (wt. 0.2270 1 0 0000 1 0000 0.5000 fraction) Benzene Content (wt. 0.0005 i 0.0000 0.0092 0.0092 fraction) Toluene Content (wt. 0.0005 I 0.0000 0.0346 0.0346 fraction) Ethylbenzene (wt. 0.0002 0.0000 0.0023 0.0023 fraction) Xylenes Content(wt. 0.0007 0.0000 0.0276 0.0276 fraction) n-hexane Content(wt. 0 0022 0.0000 0.0672 0.0670 fraction) *Other equipment type includes compressors, pressure relief valves, relief valves, diaphragms, drains, dump arms, hatches, instrument meters, polish rods and vents TOC Emission Factors (kg/hr-component) Water/Oil Component Gas Service Heavy Oil I Light Oil Service Connectors 2.0E-04 7.5E-06 2.1E-04 1.1E-04 Flanges 3.9E-04 3.9E-07 1.1E-04 2.9E-06 Open-ended Lines 2.0E-03 it1 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 I 7.5E-03 1.4E-02 Source: EPA-453/R95-017 Compliance with emissions limits in this permit will be demonstrated by using the TOO emission factors listed in the table above with representative component counts, multiplied by the VOC content from the most recent gas and liquids analyses. Point 005: Emission Factors - Emission Factors— Uncontrolled Controlled C_AS Pollutant lb/MMBtu g/bhp-hr Ib/MMBtu J g/bhp-hr NOx 31785 11.41 0.7787 2.80 CO 4.0783 14.64 I 1.3377 4.80 VOC 0.2786 1.00 0.2786 1.00 50000 Formaldehyde 0.0205 0.07 0.0205 0.07 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 AIRS ID: 123/9OA4 Page 15 of 23 olor Depa en P li Health and Environment it Pollution Control Division ion Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr 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 1279 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer 0 CO Manufacturer 0 VOC Reg. 7 Limit 0 50000 Formaldehyde AP-42; Table 3.2-3 (7/2000); 0 Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas Point 006: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant Ib/MMBtu g/bhp-hr Ib/MMBtu g/bhp-hr NOx 3.1785 11.41 0.7787 2.80 CO 4.0783 14.64 1.3377 4.80 VOC 0.2786 1.00 0.2786 1.00 50000 Formaldehyde 0.0205 0.07 0.0205 0.07 67561 Methanol 0.0031 0.01 0.0031 0.01 75070 Acetaldehyde 0.0028 0.01 0.0028 0.01 107028 Acrolein 0.0026 0.01 0.0026 0.01 71432 Benzene 0.0016 0.01 0.0016 0.01 106990 1,3-Butadiene 0.0007 0.00 0.0007 0.00 108883 Toluene 0.0006 0.00 0.0006 0.00 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 7914 Btu/hp-hr, a site-rated horsepower value of 84, and a fuel heat value of 1279 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Manufacturer 0 _ CO Manufacturer 0 _ VOC Reg. 7 Limit 0 AIRS ID: 123/9CA4 Page 16 of 23 rolora.a Depar. neneof P blic-Health and Environment 5, ! • ,55 5555 F 4 !'Air Pollution Control Division t. CAS F ,Pollutant tfncontrolledEESource r,Controlled EF Source 50000 Formaldehyde AP-42; Table 3.2-3 (7/2000); 0 Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42: Table 3.2-3 (7/2000). I No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42, Table 3.2-3 (7/2000); No Control Natural Gas 106990 1.3-Butadiene AP-42: Table 3.2-3 (7/2000): No Control Natural Gas _ 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 6) In accordance with C.R.S. 25-7-114.1, each Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years from the date it was received by the Division.A revised APEN shall be submitted no later than 30 days before the five-year term expires. Please refer to the most recent annual fee invoice to determine the APEN expiration date for each emissions point associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) Point 006: This engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18. 2008 Federal Register posting — effective March 18. 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/area/fr18ja08.pdf 8) Point 005, Point 006: This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20. 2010 Federal Register posting - effective October 19. 2010). The August 20, 2010 amendments to include requirements for existing engines located at area sources and existing engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.gov/ttn/atw/rice/fr20au10.pdf Additional information regarding area source standards can be found on the EPA website at http://www.epa.gov/ttn/atw/area/arearules.html 9) This facility is classified as follows. Applicable Status Requirement Synthetic Minor Source of: HAPS Operating Permit Major Source of: VOC NANSR Major Source of: VOC MACT ZZZZ Area Source Requirements: Applicable NSPS KKK Not Applicable NSPS 0000 Not Applicable AIRS ID: 123/9CA4 Page 17 of 23 � olor )Depa '" en + .Ii -Health and Environment '� •it Pollution Control Division 10) Full text of the Titl- ! •+ ec , .'f el ic Co.,-= Federal Regulations can be found at the website listed below- http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A— Subpart KKKK NSPS Part 60, Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ— Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN— Subpart XXXXXX 11) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: www.colorado.gov/cdphe/oilgasperrnits AIRS ID: 123/9CA4 Page 18 of 23 #5 *7,V olor ,Depar,°nenMf Pfiblic Health and Environment 511 g -Al fat fr 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 shah 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 AIRS ID: 123/9CA4 Page 19 of 23 % d a olor Depa en' 'Ii Health and Environment •it Pollution Control Division requirements applicab, <g 17 nt of .sions from the temporary replacement engine shall be made as set forth in section 2.2. 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. The AOS cannot be used for the permanent replacement of an entire engine at any source that is currently a major stationary source for purposes of Prevention of Significant Deterioration or Non- Attainment Area New Source Review ("PSD/NANSR") unless the existing engine has emission limits that are below the significance levels in Reg 3, Part D, II.A.42. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that "based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. Nothing in this AOS shall preclude the Division from taking an action, based on any permanent engine replacement(s), for circumvention of any state or federal PSD/NANSR requirement. Additionally, in the event that any permanent engine replacement(s) constitute(s) a circumvention of applicable PSD/NANSR requirements, nothing in this,AOS shall excuse the owner or operator from complying with PSD/NANSR and applicable permitting requirements. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). AIRS ID: 123/9CA4 Page 20 of 23 olora i °Depar_Ten of P blic Health and Environment 1 '", r (fir Pollution Control Division a7 }'5 a The owner or operator } l`�' 'j p rte!-;gpn�uct,,a Eaferetice.[ttQthod�test- rFl-Neu of the portable analyzer test required by this Condition if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: http://www.colorado qov/cs/Satel I ite/C D PH E-AP/CBO N/1251596520270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. 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 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: AIRS ID: 123/9CA4 Page 21 of 23 olorl Depa en .li Health and Environment •it Pollution Control Division I VOC: The emis;is -tio J 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. 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 AIRS ID: 123/9CA4 Page 22 of 23 Colora, ':Depar 'nen(cf P bile Health and Environment 11 fir Pollution Control Division gr except for lean burn erlg{3et greater than O equal to 500 hp'and less.kap 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 . 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, § I (which is referenced in Pad 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 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: 12319OA4 Page 23 of 23 Summary of Preliminary Analysis - NG RICE Company Name Noble Energy. Inc. Permit No. 14WE0644 Facility Name Holman B15-65HNM, 66HN & Cockroft B11-62-1HN, 69-AIRS 123/9CA4/005 Facility Location SENW Section 14 T5N R64W Review Date 04/28/2014 Facility Equipment ID COMP1 Permit Engineer Reoecca Vasa Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One (1) Cummins. Model G5.9, Serial Number 46599444. natural gas-fired, naturally 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. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 4.55 PTE Calculated at (hpy) 8760 Requested (mmscf/m) 0.39 Permit limits calculated at (hpy) 8760 Fuel Heat Value(btu/scf) 1279 BSCF (Btu/hp-hr) 7914 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer 0 VOC Reg 7 Limit 0 CO Manufacturer 0 Formaldehyde AP-42,Table 3.2-3(7/2000). Natural Gas 0 SOX AP-42', Table 3.2-3(7/2000),Natural Gas No Control TSP AP-42',Table 3.2-3(7/2000). Natural Gas No Control PM10 AP-42,Table 3.2-3(7/2000) Natural Gas No Control PM2.5 AP-42.Table 3.2-3(7/2000).Natural Gas No Control Other Pollutants Describe EF sources - HAPs etc. Describe EF sources- HAPs. etc. Point Summary of Criteria Emissions (tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 9.3 2.3 9.3 75.5% VOC 0.8 0.8 0.8 0.0% CO 11.9 3.9 11.9 67.2% SOx 0.0 0.0 0.0 0.0% TSP 0.1 0.1 0.1 0.0% PM10 0.1 0.1 0.1 0.0% PM2.5 0.1 0.1 0.1 0.0% Total HAPs* 0.0 0.0 0.1 0.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants lblyr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde * 119 0.0% Methanol * * 18 0.0% Acetaldehyde * * 16 0.0% Acrolein * * 15 0.0% Benzene * * 9 0.0% 1,3-Butadiene * * 4 0.0% Toluene * * 3 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 7777 Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards (g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? MACT 7777(area source) Is this engine subject to MACT 7777 area No source requirements? Is this engine subject to NSPS JJJJ? No NSPS JJJJ Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. • Comments/Notes 0 Summary of Preliminary Analysis - NG RICE Company Name Noble Energy, Inc. Permit No. 14WE0644 Facility Name Holman B15-65HNM, 66HN & Cockroft B11-62-1HN, 69--AIRS 123/9OA4/005 Facility Location SENW Section 14 T5N R64W Review Date 04/28/2014 Facility Equipment ID COMP1 Permit Engineer Rebecca Vasil Requested Action New permit/newty reported emission Issuance No. 1 Emission Point Description • One (1) Cummins, Model G5.9, Serial Number 2LB016989, natural gas-fired, naturally 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. Natural Gas Consumption Hours of Operation Requested (mmscf/yr) 4.55 PTE Calculated at (hpy) 8760 Requested (mmscf/m) 0.39 Permit limits calculated at (hpy) 8760 Fuel Heat Value(btu/scf) 1279 BSCF(Btu/hp-hr) 7914 Emission Factor Sources Uncontrolled Controlled NOx Manufacturer 0 VOC Reg. 7 Limit 0 CO Manufacturer 0 Formaldehyde AP-42. Table 3 2-3(7/2000),Natural Gas 0 SOX AP-42.Table 3 2-317/2000) Natural Gas No Control TSP AP-42 Table 3.2-3(7/2000). Natural Gas No Control PM10 AP-42,Table 3.2-3(7/2000):Natural Gas No Control PM2.5 AP-42,Table 3.2-3(7/2000).Natural Gas No Control Other Pollutants Describe EF sources- HAPs etc. Describe EF sources- HAPs, etc. Point Summary of Criteria Emissions (tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 9.3 2.3 9.3 75.5% VOC 0.8 0.8 0.8 0.0% CO 11.9 3.9 11.9 67.2% SOx 0.0 0.0 0.0 0.0% TSP 0.1 0.1 0.1 0.0% PM10 0.1 0.1 0.1 0.0% PM2.5 0.1 0.1 0.1 0.0% Total HAPs* 0.0 0.0 0.1 0.0% 'Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants (Ib/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde * 119 0.0% Methanol * 18 0.0% Acetaldehyde 16 0.0% Acrolein * * 15 0.0% Benzene * * 9 0.0% 1,3-Butadiene * 4 0.0% Toluene 3 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 777Z Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E Standards (g/hp-hr) NOx: NA CO: NA VOC: NA Reg 7 XVI.B(Ozone NAA No requirements)applies? MACT 7777(area source) Is this engine subject to MACT ZZZZ area No source requirements? Is this engine subject to NSPS JJJJ? No NSPS JJJJ Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes 0 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Noble Energy, Inc. Permit Number: 14WE0644 Source Location: SENW Sec. 14 T5N R64W Point 001: (14) 300 BBL above ground atmospheric crude oil storage tanks Point 002: (4) 300 BBL above ground atmospheric produced water Equipment Description: storage tank. Point 003: Condensate truck loadout Point 004: Fugitive emissions AIRS ID: 123-9CA4 Date: April 25th 2014 Review Engineer: Rebecca Vasil Control Engineer: Chris Laplante Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X CP1 Transfer of Ownership APEN Exempt/Permit Exempt *If tank is a true minor source at a true minor facility, it shall be granted "Final Approval" Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered "no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? March 21, 2014 Section 4—Source Description AIRS Point Equipment Description Fourteen (14) above ground 300 bbl atmospheric condensate storage tanks. 001 Emissions from these tanks are controlled by a vapor combustor with 95% control efficiency. Four(4)above ground 300 bbl atmospheric produced water storage tank. 002 Emissions from this tank are controlled by an enclosed flare with a minimum destruction efficiency of 95%. 003 Truck loadout of condensate. 004 Fugitive emission leaks. Is this a portable source? Yes X No Page 1 Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes", for what pollutant? PM,() CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region? (Note: If"yes"the provisions of X Yes No Regulation 7, Sections XII and XVII.C may apply) Point 003: Is this source located at an oil and gas X Yes No exploration site? Point 003: If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate Yes X No (hydrocarbons that have an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Point 003: Is this source located at a facility that is considered a major source of hazardous air pollutant Yes X No (HAP) emissions? Point 003: Will this equipment be operated in any X Yes No NAAQS nonattainment area? Point 003: Does this source load gasoline into Yes X No transport vehicles? Point 002: Is this source claiming exempt status for this source based on the fraction of oil in the stored Yes X No water(less than 1% by volume crude oil on an average annual basis)? Point 002: Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Point 002: Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission Yes X No (COGCC) 805 Rule? Section 5—Emission Estimate Information AIRS Point Emission Factor Source 001 Site-specific using EPA Tanks and WinSim (Refer to Section 14 for calculations) 002 CDPHE Emission Factors (PS 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 Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 001 400,000 BBL per year Page 2 002 400,000 BBL per year 1 003 400,000 BBL per year condensate loaded Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil Heavy Liquid) Light Liquid) Connectors 2680 --- 687 342 004 Flanges 401 --- 112 22 Open-Ended Lines 31 --- --- --- Pump Seals --- 2 --- Valves i 1041 --- 677 147 Other j 370 --- 63 47 Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 001 400,000 BBL per year 002 400,000 BBL per year 003 400,000 BBL per year condensate loaded Equipment Type Gas Heavy Oil Light Oil Water/Oil (or Heavy (or Light Liquid) Liquid) Connectors 2680 --- 687 342 Flanges 401 -- 112 22 004 Open-Ended 31 --- --- Lines Pump Seals _ ___ --- --- 2 --- Valves 1041 --- 677 147 Other 370 --- 63 47 _ Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production 001 400,000 BBL per year 002 400,000 BBL per year 003 400,000 BBL per year condensate loaded Equipment Type Gas Heavy Oil (or Light Oil (or Water/Oil I Heavy Liquid) Light Liquid) Connectors 12680 --- 687 342 004 Flanges 401 --- 112 i 22 Open-Ended Lines 31 --- --- --- Pump Seals --- 2 --- Valves 1041 --- 677 147 Other 370 --- 63 47 Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted 001 01 Vapor combustor 95 002 01 Enclosed flare I 95 Section 6— Emission Summary (tons per year) Point NO, VOC CO SOx PM10 Single Total HAP HAP PTE: 001 --- 204 --- --- (n-hexane) 7.58 Page 3 • 4.4 002 --- 52.4 --- --- "' (n-hexane) 5.8 003 --- 48.4 --- --- 3.4 (n- 6.6 hexane) 004 --- 45.15 --- --- -__ 2.14 (n- 4.5 hexane) 001 --- 204 --- --- 6.8 1 7.58 Uncontrolled point (n-hexane) I 4.4 source emission rate: 002 --- 52.4 --- --- -- (n-hexane) 5.8 003 --- 48.4 --- --- 3.4 (n- 6.6 hexane) 004 --- 45.15 --- --- 2.14 (n- 4.5 hexane) 001 --- 10.2 --- _-- 0.34 0.38 (n-hexane) 002 --- 262 --- --- --- 0.22 Controlled point (n-hexane) 0.29 source emission rate: 00348.4 3.4 (n- 6.6 --- --- -- hexane) 004 --- 45.15 --- --- 2.14 (n- 4.5 hexane) Section 7-Non-Criteria /Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS # BIN Emission Rate emissions (Ib/yr) reportable Rate(lb/yr) Point 001 Benzene 71432 A 1,560 Yes 78 n-Hexane 110543 C 13,600 Yes 680 Point 002 Benzene 71432 A 2,800 Yes 140 n-Hexane 110543 C 8,800 Yes 440 Point 003 Benzene 71432 A 800 Yes B00 Toluene 108883 C 3,200 Yes 3,200 Xylenes 1130207 C 2,400 Yes 2,400 n-Hexane 110543 C 6,800 Yes 6,800 2,2,4-Trimethylpentane 540841 C 400 Yes 400 Point 004 Benzene 71432 A 620 Yes 620 Toluene 108883 C 2,100 Yes 2,100 Ethylbenzene 100414 C 180 Yes 180 Xylenes 1130207 C 1,740 Yes 1,740 n-Hexane 110543 C 4,280 Yes 4,280 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. Page 4 Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory X Yes No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method 001 01 VOC CDPHE PS Memo 05-01 Site-specific sampling VOC, Site-specific gas 004 01 HAPS I State only requirement analysis VOC, Hard 004 01 HAPS ! State only requirement count component Section 9—Source Classification What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR X MACT Is this a modification to an existing permit? Yes X No If"yes" what kind of modification? Minor Synthetic Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? VOC, HAPS For Reg. 3, Part B, III.C.1.a (emissions increase > 25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 — Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? NOx emissions are less than 40 TPY. AIRS Point Section 12— Regulatory Review Regulation 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, 001-004 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 001-004 measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. Page 5 Regulation 3-APENsConstruction Permits, Operating Permits_PSD Part A-APEN Requirements 001-004 Criteria Pollutants: (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC Part B—Construction Permit Exemptions 001-004 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) Part B, III.D.2 - RACT requirements for new or modified minor sources This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the 8-hour ozone nonattainment area, but not the 1-hour ozone area. 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). Operator is using 0.6 saturation factor(submerged fill), therefore, RACT requirements are satisfied. Regulation 6 -New Source Performance Standards 001-003 None NSPS KKK: Equipment Leaks of VOC from onshore natural gas processing plants. Affected facilities at onshore natural gas facilities (any processing site engaged in 004 the extraction of natural gas liquids from field gas,fractionation of mixed natural gas liquids (NGLs) or both). Source not subject since it is located at a wellhead site. Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS This facility is located in the 8-hr ozone control area; therefore, this facility is subject 001 to Section XII of this regulation. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... 004 Section XII.G: If facility is a not natural gas processing plant located in non- attainment area, therefore, not subject to Section XII.G. Regulation 8— Hazardous Air Pollutants 001-002 None 003 MACT EEEE: Not subject because minor source of HAPs MACT HH: If facility is MAJOR source for HAP (summation of HAPS of dehydrators 004 and fugitives), then fugitive emissions are subject to MACT HH. Source is at an E&P site (not a gas plant), therefore, not subject to MACT HH. Section 13—Aerometric Information Retrieval System Coding Information Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control o Factor CAS# (Y/N) Source (/o) 1.02 Engineer Ib/bbl VOC No Calculation 95 01 Condenste Storage 0.0039 Benzene No Engineer 95 001 Tanks lb/bbl Calculation 0.034 n-hexane No Engineer 95 lb/bbl Calculation SCC 40400301 — Fixed Roof Tank, Oil field storage of crude, breathing losses 6.2381 CDPHE PS lb/1000 gal VOC No 95 Memo 09-02 throughput Produced Water 0.1667 CDPHE PS 002 01 Storage Tanks lb/1000 gal Benzene No Memo 09-02 95 throughput 0.5238 CDPHE PS lb/1000 gal n-Hexane No 95 Memo 09-02 throughput Page 6 SCC 40400315— Fixed Roof Tank, Produced Water, working+breathing+flashing losses 0 242 IVOC No AP-42 0 Ib/bbl 0.002 i Benzene �'i No Engineer 0 Ibibbl Calculation 0.009 Toluene I No Engineer 0 lb/bbl Calculation 01 Truck Crude oil Loadout 003 0.001 Elhylbenzene No Engineer 0 lb/bbl Calculation 0.006 Xylenes No Engineer 0 lb/bbl y _ Calculation 0.018 n-hexane l No Engineer 0 lb/bbl Calculation SCC 40600132: Crude Oil: Submerged Loading (Normal Service) 01 Fugitive VOC Leak VOC Yes I EPA-453/R-95-017. NA 006 Emissions -_ - l - Table 2-4 SCC 31000220: All Equip. Leak Fugitives (Valves, flanges, connections, seals, drains) Section 14—Miscellaneous Application Notes - - AIRS Point 001 Condensate Storage Tanks Site-specific emission factor using E&P Tanks: VOC = (204 TPY*2000) /400,000 bbl/yr = 1.02 lb/bbl Benzene = (1560) /400.000 bbl/yr = 0.0039 lb/bbl n-hexane = (13,600) /400.000 bbl/yr = 0.034 lb/bbl AIRS Point 002 I Produced Water Storage Tanks State-Developed Emission factors are: - Produced Water Tank Default County Emission Factors (lb/bbl) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 0.262 0.007 0.022 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 0.178 0.004 0.010 Remainder of Colorado 0.262 0.007 0.022 State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams. Arapahoe, Boulder. Broomfield. Denver. 6 2381 0.1667 0.5238 Douglas, Jefferson. Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat _ 4.2381 0.0952 0.2381 j Remainder of Colorado 6.2381 0.1667 0.5238 This source is located in the 8-hour ozone non-attainment area (Weld County is in partial non- attainment). Page 7 AIRS Point 003 Truck crude oil Loadout Units ! Basis S 0.6 Submerged loading: dedicated normal service based on source's description/drawings P 6.14 Psia Based on extended natural gas sample M 64 Lb/lb-mole Based on extended natural gas sample OR based on EPA TANKs run T 510 Deg R Based on EPA TANKs run L 5.76 Lb/10^3 gal Value is used to calculate annual emissions of VOC 0.242 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 5.761b/10^3 gal 2.42E-01 lb/bbl Annual requested Throughput 16,800,000gal/yr Annual requested VOC emissions 967741b/yr 48.4tpy Emission factors for HAPS are: Benzene = (800 Ib/yr) /(400,000) = 0.002 lb/bbl Toluene = (3200 Ib/yr)/(400,000) = 0.009 lb/bbl Xylenes = (2400 Ib/yr) /(400,000) = 0.006 lb/bbl n-hexane= (6800 Ib/yr)/(400,000) = 0.018 lb/bbl AIRS Point 004 Fugitive emissions A permit will be issued because the uncontrolled VOC emissions are greater than 2 TPY (APEN threshold)and TOTAL FACILITY is greater than 5 TPY (permit threshold). An extended gas analysis was provided in the application dated 02/25/2014. The gas analysis was perfomed less than a year of submittal. An updated extended gas analysis will not be required because: -an extended gas analysis was performed within a year of this submittal and included with this package • • Page 8 Air Pollutant Emission Notice (APEN)—and—Application for Construction Permit OIL AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY"� Current Status(Check all that apply) Reason for APEN Submittal (Check all that apply) ( 7 : AIRS ID#': I--i> • '''r—`!`-__ i ❑ APEN update only4 - /I ® New or previously unreported battery ❑ Modification to existing sources `H ❑ Previously grandfathered battery 0 Registration for coverage under general permit no. GPO] attd - ® Synthetic minor facility cancellation request for individual permits: ® Located in the 8-hr Ozone Control Area' ® Application for or Modification of an individual permit -- ❑ Registered under general permit no. GPO] _ ❑ Administrative permit amendment? ElPermitted under individual permit: t i � L/- -/ ❑ 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 Names: Noble Energy,Inc OGCC Operator#: 100322 Mailing Address10: 1625 Broadway Suite 2200 mputney@nobleene rgyinc City: Denver State: CO Zip: 80202 E-mail: .com Contact Name: Mike Putney Phone: (303)228-4385 Fax: (303)228-4286 Tank Battery Name": Holman B15-65HNSM,66HN&Cockroft Bl 1-62-1HN,69-IHNM Number of tanks: 14 Location12(QQ Sec.Twp.Range.): SENW SEC14 T5N R64W County: Weld Total tank capacity[bbl]: 4200 Calendar year for which"Actual"data applies13: 2014 Year(s)tank(s) were placed in service14: 2013 Control Description'-: Vapor Combustor Control Efficiency1°: 95% Condensate Throughput'?[bbl/year] Requested IS: 400,000 Maximum for PTE calculation14: 400,000 Actual20: While Controls Operational?' 1 Other equipment at facility22: ' I Comments: Estimated emissions at throughputs listed above. Else AVA for requested throughput/emission values unless requesting an individual permit ❑ Check if the Division is to calculate emissions. ® Check if site-specific emission factors provided to calculate emissions�3. Emission Factor Battery Requested Emissions1s Actual Emissions2? Pollutant?' [Ib'bbl] PTE?- Uncontrolled'° Controlled?' Uncontrolled26 Controlled? 1 VOC[tons'year] 1.02 204 204 10.2 NOx[tons/year] CO [tons/year] Benzene[lbs'year] 0.0039 1,560 1,560 78 n-Hexane[lbs'year] 0.034 13,600 13.600 680 Wells serviced by this tank or tank battery28 API#: 05-123-37201 Name: Holman B15-661-IN ®Newly Reported Well API#: 05-123-37200 Name: Holman B15-651 ®Newly Reported Well API#: 05-123-37 202 Name: Cockroft Ell-62-INN ®Newly Reported Well API#: 05-123-37203 Name: Cockroft B11-69-IHNM 0 Newly Reported Well API#: Name ®Newly Reported Well API#: Name: ❑Newly Reported Well API P: Name: ❑Newly Reported Well API#: Name: ❑ Newly Reported Well The signature below indicates that I have knowledge of the facts herein set forth and that the same are true,accurate,and complete to the best of my knowledge and belief If this is a registration for coverage under general permit GPI,I further certify that this source is and will be operated in full compliance with each condition of general permit GPI. " -7- 3.20 14 Signature of Legally.Authorized Person(not a vendor or consultant) Date Mike Putney Environmental Engineer III Type or Print Name of Person Signing Above Official Title Submit this form,along with S152.90 for each Colorado Department of Public Health and Environment formation call: filing of up to 5 tank battery APENS. Include Air Pollution Control Division,APCD-SS-BI 3073 (303) • $ 692-3150 8250 General Permit fee for each new GP 4300 Cherry Creek Drive South registration to: Denver,CO 80246-1530 FORM APCD-205 Page 1 of 2 v c _ v ▪ c Lv e- G 5 C G n o = .-7-", v r = c > I w E Z c o w = m ,-,--. c - W ❑ c C 02 G C N Z .. N ,.. N N CILIA j U L. T 'v G ` c Q N> In .co - V^ a o. _ cl O — r Y U ._ 4 0' G6. Ci L V h 72 CL"`" _r- C H L c d C Q L y r' °0 N an Q c `� .. = _', C v a u E c E °C. c y ..°1. > > ° t° y s"'n r L L., 2 c .y. ,x Bar m v c. U ❑ u C V, t J o c a v o C .. c . — _ _ .. — L. c _ r ' y 3 - ▪ Z. _ E L L v _ C >' _ j I ^ c y e u U 7 i- U .. . G O c =0 c. 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W = d d . E C W m W w L" O ai 0 O w a N W rl R o w m co C O ti _ ' O C.1 C.,'ut o a y v m k C.7 E '- V .7 N 9 3 5_ ro men a c- C1. b — o o p c - in I U t ` O O o o N GO GO O O O O .Qo '� 'U V O O O C N O re; O O G O C U _0 O �- F^.i ^y II C N ' I V C O co P. 5 U L ,�t Cs LTo € c a F C cC m ° a u o 9 1' a y cc o Co .e o '- 0. v " E �a ai u d , OO 0 2 p .c co k. � o W _ o w C a z j ° Q N 9 ti N O' an to e�, co N C` b O ti d O F-I L y o O O O or N co o co co O > DI ov O 3 q a o o 0 0 o a o �, o 0 0 o a o o i Q▪ �, Ir ,- ^ ❑ o -5 7 d o (� vv1 U o �L' y O v _ a N .C -C- N�. C a t oo y = vv .., - _a-5OUi a E W e `C an g I^ ¢. .N c a ao.- �i V] S v ❑ c �? W OF ,L v VCal .. o F J R= y cc cu 21 cei y C L. O m N c,t'l = a o o -o " E d E O L. V1 -k N N :° t 6 t eo U " } E .12 u y C Q O C A c w =', c w _ 7 �' J, W.+ C ti C O m ` C o 0 w y C h co E ..; 0 ❑ r 4 z F' E c o "7 v Op e O •.- u y ;_ E .4 Co c4 m 'm^ � w a A a' a� .Q L p o °' L)• o Np3 5 i o o c c E E ? 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