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Home My WebLink About20152875.tiff CISPHE COLORADO co Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150 0 St RECEIVED PO Box 758 Greeley, CO 80632 AUG 2 6 2015 August 24, 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On August 26, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Noble Energy, Inc. - Coalview GO1 Econode. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the beginning of the public notice period. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health It Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, 7 Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure -3(- x06 ec.?o1W, }tL i v 2015-2875 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.cotorado.govi John W. Hickentooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer 76"%!. I 1F\ CDPHE Air Pollution Control Division 41, CO P...ONotice of a Proposed Project or Activity Warranting Public Comment Website Title: Noble Energy, Inc. - Coalview GO1 Econode - Weld County Notice Period Begins: August 26, 2015 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: Coalview G01 Econode Oil and Gas Production Facility NESE, Section1, T4N, R65W Weld County The proposed project or activity is as follows: The applicant proposes to operate eight (8) low pressure separators and two (2) Vapor Recovery Towers with emissions during vapor recovery unit downtime, one (1) 3,228 BBL tank used for storage of produced water, one (1) 6456 BBL storage tank for storage of condensate, and loadout of condensate from the site via tanker trucks. Emissions from each of these operations will be controlled by enclosed flares. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Part B, Section III.C due to the following reason(s): • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (25 tpy in a non-attainment area and/or 50 tpy in an attainment area) • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 15WE0448 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Bradley Eades Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd®state.co.us COLORADO 1 I Aleia7 . .,..., ..F_. 4 a STATE OF COLORADO of Soto.. �LOR D• D'.,.- RTC .. •F PUBL C HEALTH AND ENVIRONMENT lye ,, , AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 #r */ \`*1876, CONSTRUCTION PERMIT PERMIT NO: 15WE0448 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 exploration and production facility known as the Coalview G01 Econode, located in the NESE Sec. 1, T4N, R65W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID Venting of gas produced by Vapor Recovery Towers (VRTs) during VRT VOC 005 vapor recovery unit (VRU) downtime. Emissions are controlled by Burners enclosed flare(s). Each flare has a minimum control efficiency of 95%. Venting of gas produced by Low-Pressure Gas/Liquid Separators LP VOC during vapor recovery unit (VRU) downtime. Emissions are Burners 006 controlled by enclosed flare(s). Each flare has a minimum control efficiency of 95%. Truck Hydrocarbon Loadout to Tanker Trucks. Emissions from the Loadout 007 loadout are routed to an enclosed flare. Produced One (1) above ground 3,228 bbl produced water storage tank. Water 008 Tank consists of six (6) liquid manifold storage vessels. Emissions from the tank are routed to enclosed flare(s). Tank One (1) above ground 6,456 bbl condensate storage tank. Tank Battery 009 consists of twelve (12) liquid manifold storage vessels. Emissions from the tank are routed to enclosed flare(s). 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: AIRS ID: 123/2932 Page 1 of 13 olor. Depa en . • •Ii Health and Environment it Pollution Control Division REQUIREMENTS :' - •" I _ , - TH• TION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after commencement of operation or issuance of this permit, whichever comes later, 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 commencement of operation or issuance of this permit, whichever comes later, 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 & 006: Within one hundred and eighty (180) days after issuance of this permit, the operator shall install and operate a flow meter to monitor and record volumetric flowrate of natural gas vented from the low-pressure separators and vapor recovery towers. The operator shall use the gas flow rate listed in the application for the actual flow rate until the flow meter is installed, not to exceed one hundred and eighty (180) days after issuance of this permit. 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) AIRS ID: 123/2932 Page 2 of 13 olor Depa` en f P li Health and Environment it Pollution Control Division Annual Limit Facility AIRS Tons per Year Equipment ID Point NO VOC CO Emission Type X VRT VOC 005 --- 3.9 --- Point Burners LP VOC 006 --- 5.3 --- Point Burners Truck Loadout 007 --- 6.7 --- Point Produced 008 --- 2.4 --- Point Water Tank Battery 009 --- 37.6 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 VRT VOC 005 Enclosed Flare(s) VOC, HAPs Burners LP VOC 006 Enclosed Flare(s) VOC, HAPs Burners Truck 007 Enclosed Flare VOC, HAPs Loadout Produced 008 Enclosed Flare(s) VOC, HAPs Water Tank 009 Enclosed Flare(s) VOC, HAPs Battery AIRS ID: 123/2932 Page 3 of 13 olor. jk Depa en - • •Ii Health and Environment II •it Pollution Control Division 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 rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID VRT VOC 005 Gas routed to combustors from VRTs 2.2 MMSCF/yr Burners LP VOC 006 Gas routed to combustors from Low- 7.0 MMSCF/yr Burners Pressure Separators Truck 007 Condensate Loaded 921,625 BBUyr Loadout Produced 008 Produced Water Throughput 365,000 BBUyr Water Tank 009 Condensate Throughput 912,500 BBUyr Battery Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall monitor and record throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. 10. Point 005 & 006: Upon installation of a flow meter, the owner or operator shall continuously monitor and record the volumetric flowrate of natural gas vented from all separators using a flow meter. The flow meter shall continuously measure flowrate and record total volumetric flow vented to the enclosed flares from all low-pressure separators and VRTs during VRU downtime. The owner or operator shall use monthly throughput records to demonstrate compliance with the limits specified and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 11. Point 005, 006, 008 & 009: 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) 12. Point 005 - 009: This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. Point 005 & 006: The separation equipment, including low-pressure separators and VRTs, covered by this permit is subject to Regulation 7, Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98%for hydrocarbons. AIRS ID: 123/2932 Page 4 of 13 olor Depa en P •li Health and Environment it Pollution Control Division 14. Point 005, 00 I • luti equi - :-t covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). If a flare or other combustion device is used to control emissions of volatile organic compounds to comply with Section XVII, it shall be enclosed, have no visible emissions during normal operations, and be designed so that an observer can, by means of visual observation from the outside of the enclosed flare or combustion device, or by other convenient means approved by the Division, determine whether it is operating properly. The operator shall comply with all applicable requirements of Section XVII. 15. Point 005, 006, 008 & 009: Per regulation No. 7, Section XVII.B.2.d, all combustion devices used to control emissions of hydrocarbons must be equipped with and operate an auto-igniter as follows: o If combustion device was installed on/after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device. o If combustion device was installed before May 1, 2014, must be equipped with an operational auto-igniter by or before May 1, 2016, or after the next combustion device planned shutdown, whichever comes first. 16. Point 008 & 009: The storage tanks covered by this permit are subject to the emissions control requirements in Regulation No. 7, Section XVII.C.1.b. The owner/operator must install and operate air pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. The source shall follow the inspection requirements of Regulation No. 7, Section XVII.C.1.d. and maintain records of the inspections for a period of two years, made available to the Division upon request. This control must be achieved according to the following schedule: o If storage tank was constructed on/after May 1, 2014, within 90 days of the date that the storage tank commences operation; o If storage tank was constructed before May 1, 2014, by May 1, 2015. 17. Point 008 & 009: The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation No. 7, Section XVII.C.2. This storage tank shall be operated without venting hydrocarbon emissions from the thief hatch (or other access point to the tank) or pressure relief device during normal operation, unless venting is reasonably required for maintenance, gauging, or safety of personnel and equipment. The owner/operator must develop, certify, and implement a documented STEM plan to identify, evaluate, and employ appropriate control technologies, monitoring practices, operational practices, and/or other strategies designed to meet these requirements. Compliance is required on the following schedule: o A storage tank constructed on/after May 1, 2014 must comply and implement a STEM Plan within 90 days of the storage tank commencing operation; o A storage tank constructed before May 1, 2014, must comply and implement a STEM Plan by May 1, 2015. Approved instrument monitoring method inspections must begin within ninety (90) days of the Phase-In Schedule in Table 1, or within thirty (30) days for storage tanks with uncontrolled actual VOC emissions greater than 50 tons per year. AIRS ID: 123/2932 Page 5 of 13 Iolorl Depa en . - •Ii Health and Environment I •it Pollution Control Division Following the -.pr- -=en - • - - 'ng -d inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 — Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In Uncontrolled Actual VOC Monitoring Method ("AIMM") Schedule Emissions (tpy) Inspection Frequency >6 and < 12 Annually January 1, 2016 > 12 and < 50 Quarterly July 1, 2015 > 50 Monthly January 1, 2015 The owner/operator shall maintain records in accordance with Regulation No. 7, Section XVII.C.3. and make them available to the Division upon request. The owner or operator shall maintain records of STEM, including the plan, any updates, and the certification, for the life of the storage tank. The owner/operator will maintain records of all required inspections and monitoring for a period of two years. 18. Point 009: 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. 19. Point 007: 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) 20. Point 007: 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 on site at the time of the inspection to ensure compliance with the conditions (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. 21. Point 007: 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. AIRS ID: 123/2932 Page 6 of 13 olor.' Depa en P li Health and Environment ir Pollution Control Division 22. Point 007: Tha- , or -' tR0 7 oa3I ntrol ions shall: a. Install and operate the vapor collection and return equipment to collect vapors during loading of tank compartments of outbound transport trucks. b. Include devices to prevent the release of vapor from vapor recovery hoses not in use. c. 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. 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. OPERATING & MAINTENANCE REQUIREMENTS 23. Point 005 - 009: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 24. Point 006: The operator shall complete an initial site specific extended gas analysis within one hundred and eighty days (180) after commencement of operation or issuance of this permit, whichever comes later, of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of testing shall be used to calculate a site-specific emission factor for the pollutant referenced above (in units of lb/MMSCF gas vented) using Division approved methods. Results of site-specific sampling and emissions factor analysis shall be submitted to the Division as part of the self-certification and demonstrate that the VOC emissions factor established in the permit application for this emissions point is valid. 25. Point 005, 006, 008 & 009: The owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions. "Visible Emissions" means observations of smoke for any period or periods of duration greater than or equal to one (1) minute in any fifteen (15) minute period during normal operation. (Reference: Regulation No. 7, Section XVII.A.II) AIRS ID: 123/2932 Page 7 of 13 olor. Depa en . - di Health and Environment A it Pollution Control Division ADDITIONAL REQ ' N 26. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NOr) 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. 27. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) 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 28. 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. 29. 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 AIRS ID: 123/2932 Page 8 of 13 olor , Depa en- P li Health and Environment it Pollution Control Division and has beenx. .y • a ®: c. in in all cts 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. 30. 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. 31. 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. 32. 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. 33. 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. 34. 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: Bradley Eades Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Noble Energy, Inc. AIRS ID: 123/2932 Page 9 of 13 olor- Depa en •. - •li Health and Environment I ' 4 it Pollution Control Division Notes to Permit Holder - me o ' •e a -. 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The 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.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 Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (Ib/yr) Benzene 71432 248 No 13 n-Hexane 110543 2279 Yes 114 005 Toluene 108883 379 Yes 19 Ethylbenzene 100414 23 No 1 Xylenes 1330207 45 No 2 Benzene 71432 299 Yes 15 n-Hexane 110543 2743 Yes 137 006 Toluene 108883 458 Yes 23 Ethylbenzene 100414 21 No 1 Xylenes 1330207 49 No 3 Benzene 71432 534 Yes 27 007 n-Hexane 110543 4272 Yes 214 Toluene 108883 801 Yes 40 Benzene 71432 2555 Yes 128 008 n-Hexane 110543 8030 Yes 402 AIRS ID: 123/2932 Page 10 of 13 T'%oiorai Depa en P li Health and Environment it Pollution Control Division Un Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (lb/yr) reportable? (Ib/yr) Benzene 71432 2646 Yes 132 009 n-Hexane 110543 24546 Yes 1227 Toluene 108883 4106 Yes 205 009 Ethylbenzene 100414 183 No 9 Xylenes 1330207 456 Yes 23 5) The emission levels contained in this permit are based on the following emission factors: Point 005: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled Ib/MMscf lb/MMscf NOx --- 261.39 261.39 CDPHE CO --- 664.08 664.08 CDPHE VOC 67.39 70647.00 3532.35 Benzene 0.11 115.22 5.76 Aspen HYSYS V8.6 Toluene 0.17 176.00 8.80 n-hexane 1.01 1059.00 52.95 Note: The uncontrolled VOC and HAP emissions were calculated based on a HYSYS model to estimate the VOC and HAP content of the stream and stream flow assuming 438 hr/yr VRU downtime. The controlled emissions for this point are based on the flare control efficiency of 95%. Point 006: Weight Emission Emission Pollutant Fraction of Factors Factors Source Gas (%) Uncontrolled Controlled lb/MMscf lb/MMscf NOx --- 111.27 111.27 CDPHE CO --- 282.70 282.70 CDPHE VOC 40.20 30074.00 1503.70 Benzene 0.06 43.00 2.15 Aspen HYSYS V8.6 Toluene 0.09 66.00 3.30 n-hexane 0.53 395.00 19.75 Note: The uncontrolled VOC and HAP emissions were calculated based on a HYSYS model to estimate the VOC and HAP content of the stream and stream flow assuming 600 hr/yr VRU downtime. The controlled emissions for this point are based on the flare control efficiency of 95%. Point 007: Emission Factors - Uncontrolled Pollutant lb/BBL loaded Source VOC 0.2900 AP-42 Benzene 0.0006 AP-42 n-Hexane 0.0046 AP-42 AIRS ID: 123/2932 Page 11 of 13 olor.II . Depa en . ' .I., Health and Environment I it Pollution Control Division Ilk am In low Uncontrolled Pollutant lb/BBL loaded Source Toluene 0.0009 AP-42 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) =7.88 psia M (vapor molecular weight) =60 Ib/Ib-mol T(temperature of liquid loaded)= 512.45°R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by multiplying the mass fraction of each NCRP in the vapors (from Hysys model) by the VOC emission factor. Point 008: Emission Factors Pollutant Uncontrolled Source lb/BBL Produced Water Throughput VOC 0.262 CDPHE n-Hexane 0.022 CDPHE Benzene 0.007 CDPHE Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 009: Emission Factors Uncontrolled Pollutant lb/BBL Source Condensate Throughput VOC 1.6442 n-Hexane 0.0269 Benzene 0.0029 HYSYS V.8.6 Toluene 0.0045 Ethylbenzene 0.0002 Xylenes 0.0005 Note: The controlled emissions for this point are based on the flare control efficiency of 95%. 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 AIRS ID: 123/2932 Page 12 of 13 olor Depa en f P li Health and Environment it Pollution Control Division associated with thi or g cific ion date call the Division at (303)-692-3150. 7) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, n-Hexane, Total HAPs NANSR Synthetic Minor Source of: VOC MACT HH Major Source Requirements: Not Applicable Area Source Requirements: Not Applicable 8) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website listed below: http://ecfr.gpoaccess.gov/ Part 60: Standards of Performance for New Stationary Sources NSPS 60.1-End Subpart A—Subpart KKKK NSPS Part 60,Appendixes Appendix A—Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A—Subpart Z MACT 63.600-63.1199 Subpart AA—Subpart DDD MACT 63.1200-63.1439 Subpart EEE—Subpart PPP MACT 63.1440-63.6175 Subpart QQQ—Subpart YYYY MACT 63.6580-63.8830 Subpart ZZZZ—Subpart MMMMM MACT 63.8980-End Subpart NNNNN—Subpart X)O(XXX 9) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: http://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/2932 Page 13 of 13 Division Information Engineer: Bradley Eades Control Engineer: Chris Laplante Review Date: 06/05/2015 Application Date: 02/23/2015 Facility Identifiers Permit No. 15WE0448 Potentially located in ozone nonattainment area AIRS County# 123 Weld Facility# 2932 Facility Type: exploration and production facility ❑� Located in the 8-hour non-attainment area? O True Minor Synthetic Minor for: P VOC r NOx r CO Administrative Information Company Name: Noble Energy, Inc. Source Name: Coalview G01 Econode Source Location: NESE Sec. 1, T4N, R65W SIC: 1311 Address 1: Noble Energy, Inc. Mailing Address 2: 1625 Broadway,Suite 2200 Address ty,State Zip: Denver, CO 80202 Name: Shaun Higgins Person To Phone: 720-587-2459 Contact Fax: 303-228-4362 Email: shaun.higgins@nblenergy.com 'Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the Coalview G01 Econode, located in the NESE Sec. 1, T4N, R65W,Weld County,Colorado. Point Name Type Control Action VRT VOC Newly 005 Separator Venting Flare reported Burners source LP VOC Newly 006 Separator Venting Flare reported Burners source Truck Newly 007 Loadout Loadout Flare reported source Produced Newly 008 Water Water Tanks Flare reported source Newly 009 Tank Battery Condensate Tanks Flare reported source Two(2)VRTs controlled by four(4)enclosed flares during VRU downtime.Flare has a minimum control 005 efficiency of 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: recompressed Natural gas venting from a well head separator.Emissions from this source are recompressed. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(Q) 2.151675 MMscf/yr 245.625 scf/hr MW 39.70 Ib/Ib-mol 0.005895 MMscf/d mass fraction lb/hr lb/yr tpy CO2 0.025 0.65 5702.28 2.85 N2 0.000 0.00 22.54 0.01 methane 0.061 1.56 13658.42 6.83 ethane 0.240 6.17 54070.23 27.04 propane 0.325 8.36 73273.16 36.64 isobutane 0.069 1.78 15596.75 7.80 n-butane 0.152 3.91 34213.68 17.11 isopentane 0.045 1.15 10074.78 5.04 n-pentane 0.047 1.22 10660.78 5.33 3-Mpentane 0.014 0.36 3177.95 1.59 n-Heptane 0.006 0.16 1419.94 0.71 n-Octane 0.001 0.02 202.85 0.10 n-Nonane 0.000 0.00 0.00 0.00 n-Decane 0.001 0.03 247.93 0.12 Benzene 0.001 0.03 247.93 0.12 Toluene 0.002 0.04 383.16 0.19 E-Benzene 0.000 0.00 22.54 0.01 Xylenes 0.000 0.01 45.08 0.02 n-Hexane 0.010 0.26 2276.40 1.14 224-TMP 0.000 0.01 45.08 0.02 VOC mass fraction: 0.6739 Total VOC(Uncontrolled) 75.94 Notes MW and mass fractions from Hysys Version 8.6 results submitted with application.Model was carried out using pressurized liquid samples collected from 4 wells at the Coalview facilty.("Material Stream:VRT Vapor to Sales or WH Comp.") Emissions are based on 8760 hours of operation per year. I calculated the average MW of C8+based on the average MW on the analysis for the gas. 15WE0448.CP1.xlsm Two(2)VRTs controlled by four(4)enclosed flares during VRU downtime.Flare has a minimum control 005 efficiency of 95%. Flaring Information Equipment Description Flare to combust low-pressure separator gas during VRU downtime. Manufacturer Cimarron Model TBD Serial Number TBD Gas Heating Value 2212.32 Btu/scf Throughput 4760.193636 MMBtu/yr Overall Control 95.00% Combustion emission factor source: CDPHE Inter-Office Communication 0.0037 NOX/IbVOC 0.0094 JIb CO/IbVOC Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 70647 lb/MMscf 3532.35 lb/MMscf 76.00 tpy 3.80 tpy Aspen HYSYS V8. Nox 261.39 lb/MMscf 261.39 lb/MMscf 0.28 tpy 0.28 tpy CDPHE CO 664.08 lb/MMscf 664.08 lb/MMscf 0.71 tpy 0.71 tpy CDPHE Benzene 115.22 lb/MMscf 5.76 lb/MMscf 247.93 lb/yr 12.40 lb/yr Aspen HYSYS V8. n-Hexane 1059.00 lb/MMscf 52.9500 lb/MMscf 2278.62 lb/yr 113.93 lb/yr Aspen HYSYS V8. Toluene 176.000 lb/MMscf 8.8000 lb/MMscf 378.69 lb/yr 18.93 lb/yr Aspen HYSYS V8. Xylenes 20.950 lb/MMscf 1.0475 lb/MMscf 45.08 lb/yr 2.25 lb/yr Aspen HYSYS V8. Ethylbenzene 10.475 lb/MMscf 0.5237 lb/MMscf 22.54 lb/yr 1.13 lb/yr Aspen HYSYS V8. Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 Miscellaneous Notes Met with Shaun Higgins on 06/16/2015 regarding the structure of this permit and site-design considerations.After continued discussion with Met with Shaun Higgins on 06/16/2015 regarding the structure of this permit and site-design considerations.After continued discussion with Shaun following the meeting,a flow meter was installed on the LP separator line to the combustors to simplify monitoring and compliance demonstration.Noble has also agreed to install a flow meter on the vapor line to the combustors from the VRT within 180 days after issuance of permit. After discussion with S.Higgins,combustion emission factors for NOx and CO used are derived from CDPHE inter-office communication Re:Condensate Flare Emission Factors.Although the emissions factors were derived for use with storage tanks,their use is approved here since the gas routed to the ECDs is produced from low pressure flash. Emission factors based on the calculations in this PA varied slightly from those calculated by Noble.Differences may be attributed to rounding,therefore values in the"Emissions Summary Table"above reflect values reported on the APEN. Emission Estimates used in permit are based on 600 hrs/yr VRU downtime. After discussion with Shaun Higgins,it was determined that it is acceptable for the facility to use the modeled VRT vent rate(from the application)with an assumed 5%'VRU downtime"to the combustors as the actual vent rate until the flow meter is installed.This is not to exceed 180 days. 15WE0448.CP1.xlsm Eight(8)low-pressure separators controlled by six(6)enclosed flares during VRU downtime.Each 006 combustor has a minimum control efficiency of 95%. Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to a flare Natural gas venting from a well head separator.Emissions from this source are routed to a flare. Note:Under normal operation emissions from this source are routed to VRUs and recompressed into the sales line.During period of VRU downtime,emissions are routed to enclosed combustors.This permit addresses emissions during VRU downtime. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q`MW`Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/lb-mol)at 60F and 1 atm Throughput(Q) 6.944 MMscf/yr 792.6940639 scf/hr MW 28.34 Ib/Ib-mol 0.019024658 MMscf/d mass fraction lb/hr lb/yr tpy CO2 0.048 2.84 24871.72 12.44 N2 0.002 0.11 986.56 0.49 methane 0.279 16.51 144609.07 72.30 ethane 0.270 15.99 140039.74 70.02 propane 0.213 12.64 110702.53 55.35 isobutane 0.039 2.30 20146.61 10.07 n-butane 0.083 4.91 42993.29 21.50 isopentane 0.024 1.39 12202.20 6.10 n-pentane 0.025 1.47 12877.22 6.44 n-Hexane 0.005 0.31 2751.99 1.38 3-Mpentane 0.007 0.44 3842.40 1.92 heptanes 0.003 0.20 1713.50 0.86 224-TMP 0.000 0.01 51.92 0.03 Benzene 0.001 0.04 311.55 0.16 Toluene 0.001 0.05 467.32 0.23 Ethylbenzene 0.000 0.00 0.01 0.00 Xylenes 0.000 0.01 51.92 0.03 n-Octane 0.001 0.03 259.62 0.13 n-Nonane 0.000 0.02 178.70 0.09 n-Decane 0.001 0.04 311.55 0.16 VOC mass fraction: 0.402 Total VOC(Uncontrolled) 104.43 Notes MW and mass fractions from Hysys Version 8.6 results submitted with application.Model was carried out using pressurized liquid samples collected from 4 wells at the Coalview facilty.("Material Stream:Vapor to Sales or WH Comp.") Emissions are based on 8760 hours of operation per year. • 15WE0448.CP1.xlsm Eight(8)low-pressure separators controlled by six(6)enclosed flares during VRU downtime.Each 006 combustor has a minimum control efficiency of 95%. Flaring Information Equipment Description Six(6)Enclosed Flares to combust lowpressure separator gas during VRU downtime. Manufacturer Cimarron Model TBD Serial Number TBD Gas Heating Value 1582.416 Btu/scf Throughput 10988.2967 MMBtu/yr Overall Control 95.00% Combustion emission factor source: CDPHE Inter-Office Communication 0.0037 Ilb NOX/IbVOC 0.0094 Ilb CO/IbVOC Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 30074 lb/MMscf 1503.70 lb/MMscf 104.42 tpy 5.22 tpy Aspen HYSYS V8. Nox 111.27 lb/MMscf 111.27 Ib/MMscf 0.39 tpy 0.39 tpy CDPHE CO 282.70 lb/MMscf 282.70 lb/MMscf 0.98 tpy 0.98 tpy CDPHE Benzene 43.00 lb/MMscf 2.15 lb/MMscf 298.59 lb/yr 14.93 lb/yr Aspen HYSYS V8. n-Hexane 395.00 Ib/MMscf 19.7500 lb/MMscf 2742.88 lb/yr 137.14 lb/yr Aspen HYSYS V8. Toluene 66.000 Ib/MMscf 3.3000 lb/MMscf 458.30 lb/yr 22.92 lb/yr Aspen HYSYS V8. Xylenes 7.000 lb/MMscf 0.3500 lb/MMscf 48.61 lb/yr 2.43 lb/yr Aspen HYSYS V8. Ethylbenzene 3.000 Ib/MMscf 0.1500 lb/MMscf 20.83 lb/yr 1.04 lb/yr Aspen HYSYS V8. Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'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.' AQCC Regulation 2 Section I.A applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 Miscellaneous Notes Met with Shaun Higgins on 06/16/2015 regarding the structure of this permit and site-design considerations.After continued discussion with Shaun following the meeting,a flow meter was installed on the LP separator line to the combustors to simplify monitoring and compliance demonstration.Noble has also agreed to install a flow meter on the vapor line to the combustors from the VRT within 180 days after issuance of permit. After discussion with S.Higgins,combustion emission factors for NOx and CO used are derived from CDPHE inter-office communication Re:Condensate Flare Emission Factors.Although the emissions factors were derived for use with storage tanks,their use is approved here since the gas routed to the ECDs is produced from low pressure flash. Emission factors based on the calculations in this PA varied slightly from those calculated by Noble.Differences may be attributed to rounding,therefore values in the"Emissions Summary Table"above reflect values reported on the APEN. Emission Estimates used in permit are based on 600 hrs/yr VRU downtime. After discussion with Shaun Higgins,it was determined that it is acceptable for the facility to use the modeled VRT vent rate(from the application)with an assumed 5°%'VRU downtime"to the combustors as the actual vent rate until the flow meter is installed.This is not to exceed 180 days. 15WE0448.CP1.xlsm 007 Hydrocarbon Loadout to Tanker Trucks Calculations L=12.46*S*P*M/T(AP-42:Chapter 5.2,Equation 1) L=loading losses in lb per 1000 gallons loaded Factor Meaning Value Units Source S Saturation Factor 0.6 AP-42 P True Vapor Pressure 7.88 psia AP-42 M Molecular Weight of Vac 60 lb/lb-mole AP-42. T Liquid Temperature 512.45 deg.R Field Data L 6.90 lb/10^3 gal 2.90E-01 lb/bbl Annual requested Throughput 921625 BBL/yr 38708250 gal/yr Annual requested VOC emissions 266992 lb/yr 133.50 tpy Control: Flare Efficiency: 95.00% NCRPs Component Mass Fraction Benzene 0.0020 n-hexane 0.0160 Toluene 0.0030 Xylenes 0.0000 Source: Based on tank flash emission speciation from Hysys Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.2900 lb/bbl 133.64 tpy 6.68 tpy AP-42 Benzene 0.0006 lb/bbl 533.98 lb/yr 26.70 lb/yr AP-42 n-Hexane 0.0046 lb/bbl 4271.88 lb/yr 213.59 lb/yr AP-42 Toluene 0.0009 lb/bbl 800.98 lb/yr 40.05 lb/yr AP-42 Xylenes 0.0000 lb/bbl 0.00 lb/yr 0.00 lb/yr AP-42 Regulatory Review 'Regulation 3-APEN and Permitting Requirements Is this site considered an exploration and production location(e.g.well pad)? Yes If yes, review the following two exemptions for applicability: Does the operator unload less than 10,000 gallons(238 BBLs)per day of crude oil on an annual average basis? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 Does this operator unload less than 6,750 bbls per year of condensate via splash fill or 16,308 bbls per year of condensate via submerged fill procedure? No If yes,this emissions point is categorically exempt from permit requirements per Regulation 3,Part B,Section II.D.1.1 Miscellaneous Notes Facility has condensate tanks point 009 in this facility wide permit as well as point 001 on GP08. Point 007 represents loadout operations from both tanks. 008 One(1) above ground 3,228 bbl produced water storage tank. Tank has six(6) liquid r Emissions Calculations Requsted Throughput 365000 bbl Control Flare Efficiency 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 0.262 lb/bbl 47.815 tpy 2.39075 tpy CDPHE Benzene 0.007 lb/bbl 2555 lb/yr 127.75 lb/yr CDPHE n-Hexane 0.022 lb/bbl 8030 lb/yr 401.5 lb/yr CDPHE Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 -Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation2—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 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. Miscellaneous Notes Wells serviced by this tank first date of production 11/2014. Wells include Coalview G02-63-1HN, G02-64-1HN, G02-65-1HN,G02-66-1HN, G02-67-1HN, G02-68-1HN. 009 One(1)above ground 6456 bbl condensate storage tank.Tank consists of twelve(12)liquid manifold storage vessels. Requsted Throughput 912500 bbl Control Flare Efficiency 95.00%I Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source V0C 1.6442 lb/bbl 750.2 tpy 37.51 tpy HYSYS V.8.6 Benzene 0.0029 lb/bbl 2646.25 lb/yr 132.3125 lb/yr HYSYS V.8.6 Toluene 0.0045 lb/bbl 4106.25 lb/yr 205.3125 lb/yr HYSYS V.8.6 Ethylbenzene 0.0002 lb/bbl 182.5 lb/yr 9.125 lb/yr HYSYS V.8.6 Xylenes 0.0005 lb/bbl 456.25 lb/yr 22.8125 lb/yr HYSYS V.8.6 n-Hexane 0.0269 lb/bbl 24546.25 lb/yr 1227.313 lb/yr HYSYS V.8.6 Regulatory Review • Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20%opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9(40 CFR, Part 60,Appendix A(July, 1992))in all subsections of Section II.A and B of this regulation. Section II.A.5-Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Re ulation 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 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 6-''New Source Performance Standards NSPS Kb: for storage vessels greater than 19,800 gallons after 7/23/84. This source is not subject because the tanks are prior to custody transfer and have a capacity less than 420,000 gallons(10,000 BBL) NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject to this subpart because each storage vessel emits less than 6 tpy VOC. Regulation 7-Volatile Organic Compounds XII.VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Applicant is subject to the emission control and monitoring requirements for condensate tanks since it is located in a non-attainment area. XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Applicant is currently subject to requirements of Section XVII.C since uncontrolled emissions are greater than 20 tpy VOC. Control devices used to comply are subject to Section XVII.B. AIRS(County/Plant) 123/2932 Permit No. 15WE0448 Date 6/5/2015 Controlled Controlled Actual Requested NCRP= Uncontrolled Emission Emissions Emissions PTE Ctrl. reportable Point# SCC Pollutant or CAS Factor Emisison Factor Source (tpy)* (tpy)* (tpy)* Eff% ? 005 31000205 VOC 70647 lb/MMscf Aspen HYSYS V8.6 3.8 76 95% Yes 005 31000205 NOx 261.394 Ib/MMscf CDPHE 0.3 0.3 0% No 005 31000205 CO 664.082 lb/MMscf CDPHE 0.7 0.7 0% No 005 31000205 Benzene 115.224 lb/MMscf Aspen HYSYS V8.9 12.4 247.9 95% No 005 31000205 n-Hexane 1059 lb/MMscf Aspen HYSYS V8.10 113.9 2278.6 95% Yes 005 31000205 Toluene 176 lb/MMscf Aspen HYSYS V8.11 18.9 378.7 95% Yes 005 31000205 Ethylbenzene 10.475 lb/MMscf Aspen HYSYS V8.13 1.1 22.5 95% No 005 31000205 Xylenes 20.95 Ib/MMscf Aspen HYSYS V8.12 2.3 45.1 95% No 006 31000205 VOC 30074 lb/MMscf Aspen HYSYS V8.6 5.2 104.4 95% Yes 006 31000205 NOx 111.274 lb/MMscf CDPHE 0.4 0.4 0% No 006 31000205 CO 282.696 lb/MMscf CDPHE 1 1 0% No 006 31000205 Benzene 43 lb/MMscf Aspen HYSYS V8.9 14.9 298.6 95% Yes 006 31000205 n-Hexane 395 lb/MMscf Aspen HYSYS V8.10 137.1 2742.9 95% Yes 006 31000205 Toluene 66 lb/MMscf Aspen HYSYS V8.11 22.9 458.3 95% Yes 006 31000205 Ethylbenzene 3 lb/MMscf Aspen HYSYS V8.13 1 20.8 95% No 006 31000205 Xylenes 7 lb/MMscf Aspen HYSYS V8.12 2.4 48.6 95% No 007 40600132 VOC 6.905 lb/1000 ga AP-42 6.7 133.6 95% Yes 007 40600132 Benzene 0.014 lb/1000 ga AP-42 26.7 534 95% Yes 007 40600132 n-Hexane 0.111 lb/1000 ga AP-42 213.6 4271.9 95% Yes 007 40600132 Toluene 0.021 lb/1000 ga AP-42 40 801 95% Yes 007 40600132 Xylenes 0 lb/1000 ga AP-42 0 0 No 008 40400315 VOC 6.238 lb/1000 ga CDPHE 2.4 47.8 95% Yes 008 40400315 Benzene 0.167 lb/1000 ga CDPHE 127.8 2555 95% Yes 008 40400315 n-Hexane 0.524 lb/1000 ga CDPHE 401.5 8030 95% Yes 009 40400311 VOC 39.148 lb/1000 ga HYSYS V.8.6 37.5 750.2 95% Yes 009 40400311 Benzene 0.069 lb/1000 ga HYSYS V.8.6 132.3 2646.3 95% Yes 009 40400311 n-Hexane 0.641 lb/1000 ga HYSYS V.8.6 1227.3 24546 95% Yes 009 40400311 Toluene 0.107 lb/1000 ga HYSYS V.8.6 205.3 4106.3 95% Yes 009 40400311 Ethylbenzene 0.005 lb/1000 ga HYSYS V.8.6 9.1 182.5 95% No 009 40400311 Xylenes 0.012 lb/1000 ga HYSYS V.8.6 22.8 456.3 95% Yes at O U y .0 U u O o N O C O to ,l1 aJ = E Z y U M M R o = En N eV N N cn .... 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E c� L g ti ty - rn V , _ _ a~ . up u u o > • ro u v v C7 _ U U Z Z o 0 9' 3 h Q C y' v yr 0. CW.a w 3 Z < , c• .0 1- 0et It' O i E C C g ❑ CG ❑ ❑ d d ._. ar a_' 0.L, uu Lo EIEHZEIIEI V _ 0. O c o C 00 ❑ . = N i n — O V d r-4 C 3 o zz � . o R z ,— © �+CC ro a g v 5 .-. .. =▪ ,n o c, co Oo !-2 O ❑ O o = a. v u o p _ Q .•. 7 C C N 7 O O �O O > Y = O V �O N O u n. y W M X- C 00 N et X V R ,-. A E N M W E .- V y cn a Z _ N o, a W m c o V Y C an • ai> o - o •� c c •o o ° ' E c a LT. v o U 3 •• u o Q, U � ° o U _ � = = � N zzzzz a U U a, a. L.: uo 0 o as as °�' = y y W6 611 w Z VD W N O 5 N ❑ ®❑ u Q ❑ c h o 6, C1 = x x .+. .:. c Z Z V •o no = V 0. en ' an ' r to V x .- V R o > p l0 V' '. V^ l0 Ls-) - C CC = L V R 3 1 > O o 4-i •p pp N N N N N a 2 o w N �. U o 0 R F o 0 0 0 0 o I O ° a N > aaa V O R L L U C7 U C7 U ^ /� R -0 = R \ j, N !al' m = E u u u V d l r O a O a, O r a, P P o C. R R R R cv ^ o — ad "' w E U U U U U C n Al 2 CO r! E - o 9 si-ti = -00 o an i `n O V �'-' 00 L dO p N C E C. .s. O >' R� a 0 .N aT W - C ar �' N L.° = V V, o U E Co... .. .. 7E et C V u o 4 U: a ^ ano.4�. on � a,c C7 U o0ti) co0n ❑ 1' cooE= = w oUvi o ti d ? r LC o N N vd cn O O R Vb0 L 1. 00 00 G1 C� 0, or, ._ Y N V L .. L bA _O' L A C ,� ci aj (' 'vi U v, C, L ^ > a, - O O 2 '.l i o E M M M M M a. O. Q cC r eil y i C7 cC ,I.-: R O �. > ar, y z M M M M M Q ' Z Z 0 •'DD O ..7 I O H A. m -'— >' I ¢ O N N N N N I =' .. O O ¢ U Q r) cr �.. c ° ;' a, " � 0 o at � ¢ an v, J� J� v� Z [4 Oct ° '- tuD o _ o = a, it ¢ ¢ .D o rcr, E. *7, o o o o o a O E V) — = 0 o X V] V w� R .O V 0 Q CSC L _ O JO CJ w V cC _ U ♦ ♦ .+ O 1 L Q .. 4. .0 U U V] 2 W U .- 0 -- R U O O R C. w`,, vD a V) w° H .� 3 �; C7 cn U N H Ct F M i L C," L o N N N N N N a� 7 7 ,r 7 7 7 - v c w m � 4- m i n. 0.. a a C. 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OV U Jrr >• 7 y C .� T h <a, ` W • w o u .� y v U .� ., E� o ❑ .o > ® o E E � OE T, oD 4'-! W C . •c.C7' ❑ o C «.' d a. c .o -p = N.. 0▪ a> .E `o C o 3 •>' ,L u o ¢ c R E ' w y 3 u o c o o o a _ p E R o '%t c.E o -4... L U o G' C c cn Z € = O. v CC v y C R C-. O = a=L. W O R O .� > ≥ p N U V] _.. Q C '.L Q G ., R U = .L W y . V C. •R O g. O C 0 v O u ,� .--. L y 5.0 0 'o G -y e^ c U H > U L = G O 2, . •0 G '0 �p iC Opp II _ c g 6 >• n ftl-U u Q _3 V] c r. _. R c N `O v d U v ' N FL N _ W p E \ N U 4'" E O O Y_ O C u 6 N c3 m u W 7 U C .7 o L p 4? N ('�) C v '�- CJ W CJ R U L .-+ N C ti V 'C _ v C P., C C o v >. x U oo - O 'a O r v O c R Z f+ 4; y o z o 0 _ &= O .''' w Q L c C �_' 'o E m .O .O .O .O z ¢ "C. � 'C W e 0-78'c u ?? F- " o c = Q' m d p ?,� `- v o v Z a� r C '' `'9 d w13 at W W W _._. ❑ co ° a H d ti aCi E O O u .C O m v u u N Cl.) L CJ z Z L c0 j a' O4. �` .p `+�"-+ O = O v c .�°. •E b 7 N El. O 0 O C N Q Q Q E w — [� i .�. ¢ jm u V °' o �' o '= c - o 0 0 0 0 0 0 o p'- d p © Lq c w C = `oca. c� E. chi . o .- o 0 0 0 0 o at o'61.c R .".SC.) L N u U . 'O Uj 0 0. > d y .o - Z E v' _._. v1 Q v y 4' o c E '� v �' ^ tr L �_ v -C '� `! u V - co m ai C � _ c 0 A > E o <,- o. = q c a • ad) w e t• r-' !-l ti O^ C ^ O L '-d '' v o ^ R b '"� cc! C c 2 LO — • L P. >w 1 a o >cu 0 V y N ` c E 0 a. u ` o 0 r, E �. V]CZ .W «UR. efl U u 0 c o C J W e ca x U C - ^ ^ `c° Q r 0�. -0 Q 0 0 = o oe h c ° i in o o f a m H - X c '" _ c o d a m o > n Q U Q w W H o c c - c c „ c c t o C o �z o o , o a o \ i �'>' Q 't c -L 2 s «+ W, 'E w N +7 \ C - u FL CL) 'o Q w d ❑ ❑ te 3 F. d ® N d �- a x CIO CA VD VD E&P Storage Tank Air Pollutant Emissions Notice(APEN)Addendum Form' Company Name: Noble Energy,Inc. Source Name: Coalview G01 Econode Emissions Source AIRS ID2: 123/2932/ Wells Services by this Storage Tank or Tank Battery(E&P Sites Only) API Number Name of Well Newly Reported Well 05-123-39916 Coalview G02-68-1HN - — ❑ El - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: I Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 APEN-Addendum_Tank Battery 1.docx U O ^3 y 0 0 0 0 0 v 3 C i Z O c 3 44444 >- °o ° 0 000 n w a) ar >, o c = a ,-- -. _= a X ❑ d VJ aJ 9 > U Z F CT O\ O, Z F-' O E >w a O O . . ,O ,O _ 0 ai 6) 6) ai 0.m 0 p• Q C. b° E ≤n M r< u 3 N v > J > > L U o v L N L c o 0 0 M s E a >, v 5: 0 . u 'n cut L C - m ,2-bq v E _ - v C6 N a.') y c ' 3 •0 3 L-j =.- ,. o L L a `o -0 'o E-+ Y! T ai h d C coo ,-,w W ° c> .a° E a 3 L I,- I®❑®❑❑ R H o v u W c ... d ° a H 0 ,-. L N .= a Q v • T" i F oo ovcn a 0 00 '`Q 0. 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Source Name: Coalview 601 Econode Emissions Source AIRS ID2: 123/2932/ Wells Services by this Storage Tank or Tank Battery(E&P Sites Only) API Number Name of Well Newly Reported Well 05-123-39916 Coalview G02-68-1IIN 05-123—28166 Dinner 01-01-19 ❑ 05-123-19003 Dinner 01-14 ❑ 05-123-29986 Dinner 01-15 ❑ 05-123-16857 Dinner 01-42 ❑ 05-123-24050 Dinner 01-45 ❑ 05-123-32478 Dinner PC G01-212 ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ - - ❑ Footnotes: 1 Attach this addendum to associated APEN form when needed to report additional wells. 2 If this is a newly report source that has not been assigned an AIRS ID by the APCD, enter N/A Form APCD-212 APEN-Addendum PW Tanks.docx Hello