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Home My WebLink About20153308.tiff ` CDPHE ' COLORADO T co .y' 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 1150O St PO Box 758 Greeley, CO 80632 RECEIVED October 8, 2015 OCT 1 3 2015 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On October 14, 2015, the Air Pollution Control Division will begin a 30-day public notice period for Kerr-McGee Oil and Gas Onshore LP - J-Sand North Test Facility. 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 Et Environment APCD-SS-B1 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, rf _..`' Clara Gonzales Public Notice Coordinator r Sources Program Stationary ogm a Air Pollution Control Division Enclosure �l1�bl�e�Pl)lC't c) �W 10113 2015-3308 10- 19-15 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe :. :c John W. Hickenlooper, Governor ! Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer cuPHIE Air Pollution Control Division ,124 Co Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Kerr-McGee Oil and Gas Onshore LP - J-Sand North Test Facility - Weld County Notice Period Begins: October 14, 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: Kerr-McGee Oil and Gas Onshore LP Facility: J-Sand North Test Facility Oil and Gas Well Production Facility SE SEC 36 T1 N R63W Weld County The proposed project or activity is as follows: Applicant proposes to construct an oil and gas well production facility to test the J-Sand formation for production potential 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 15WE0875 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: Christopher Kester 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 AFi STATE OF COLORADO . of coz C LORADO DEI ARTM PuuLIC HEALTH AND ENVIRONMENT ,'w 4 AIR POLLUTION CONTROL DIVISION `'4 �' TELEPHONE: (303) 692-3150 • * �' ''.4!„(876,..t/ CONSTRUCTION PERMIT PERMIT NO: 155WE0875 Issuance 1 DATE ISSUED: ISSUED TO: Kerr-McGee Oil and Gas Onshore LP THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas exploration and production facility known as the J-Sand North Test Facility, located in the SE S36 T1N R63W, Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Description ID Point Two (2) above-ground 300 bbl atmospheric condensate storage TK01-TK02 001 tanks. Emissions from tanks are controlled by enclosed flares with a minimum control efficiency of 95%. Condensate Loadout to Tanker Trucks. Emissions from the loadout TL-01 002 are controlled by enclosed flares with a minimum control efficiency of 95%. VRT 01 003 One vapor recovery tower (VRT) controlled by enclosed flares. Flares have a minimum control efficiency of 95%. PRFL 01 004 One enclosed production flare controlling emissions from separator and heater-treater. Flare has a minimum control efficiency of 95%. 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 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. AIRS ID: 123/9DDF Page 1 of 13 al olor. Depa en ' ;.Ii `Health and Environment it Pollution Control Division 2. Within one hu -- d : Y . . ',;:0) - =--men ,-• .- t 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. 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. 6. Point 004: Upon start-up of this emissions point, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas flared from each separator. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Emission Type Equipment ID Point NO), VOC CO TK01-TK02 001 -- 0.9 -- Point TL-01 002 -- 0.5 -- Point VRT-01 003 0.9 11.4 2.2 Point PRFL-01 004 30.0 74.8 60.9 Point See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) AIRS ID: 123/9DDF Page 2 of 13 olor Depar: en f P li Health and Environment it Pollution Control Division from each ennissto it, oda r el ,. nth t 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 TK01-TK02 001 Enclosed Flares VOC, HAPs TL-01 002 Enclosed Flares VOC, HAPs VRT-01 003 Enclosed Flares VOC, HAPs PRFL-01 004 Enclosed Flares VOC, HAPs 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 TK01-TK02 001 Condensate Throughput 84,000 bbl TL-01 002 Oil Loaded 84,000 bbl VRT-01 003 Condensate Throughput at VRT 67,200 bbl PRFL-01 004 Gas Vented from Separator 357.9 MMscf 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. Point 004: The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas flared from the separator(s) using a flow meter. The flow meter shall continuously measure flow rate and record total volumetric flow flared from the separator. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits specified in this permit and to calculate emissions as described in this permit. AIRS ID: 123/9DDF Page 3 of 13 I olor. ' Depa en . •l HealthandEnvironment iti PollutionControlDivisionSTATE AND FEDE • G • T' - -EP. : .- , NTS 10. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 11. Visible emissions shall not exceed twenty percent(20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.2.b shall have no visible emissions. (Reference: Regulation No. 1, Section I I.A.1. & 4.) 12. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 13. 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. (Reference: Regulation No. 1, Section II.A.5.) 14. 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. 15. 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. 16. Points 001, 003, and 004: The flare(s) covered by this permit is subject to Regulation No. 7, Section XVII.B General Provisions (State only enforceable). These requirements include, but are not limited to: • XVII.B.2.b If a 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 combustion device, or by other means approved by the Division, determine whether it is operating properly. • XVII.B.2.d.(i) All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device. 17. Point 001: The storage tanks covered by this permit are subject to the emission 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 AIRS ID: 123/9DDF Page 4 of 13 olora Depa enc f P li 'Health and Environment it Pollution Control Division v the inspections eri-_ f rift rs, ailabl he Division upon request. This control must be achieved by May 1, 2015. 18. Point 001: 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. Following the first approved instrument monitoring method inspection, owners or operators must continue conducting approved instrument monitoring method inspections in accordance with the Inspection Frequency in Table 1. Table 1 — Storage Tank Inspections Threshold: Storage Tank Approved Instrument Phase-In 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. 19. Point 002: 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) AIRS ID: 123/9DDF Page 5 of 13 . 0 . olorl Depa en •Ii Health and Environment 'it Pollution Control Division 20. Point 002: T 'r •F ',. all ' -ding a: ;m edures 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 002: 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. 22. Points 003 and 004: The separator 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. OPERATING & MAINTENANCE REQUIREMENTS 23. Points 001, 002, 003 and 004: 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. Points 001 and 003: Within ninety (90) days of commencement of operation, the operator shall complete site specific sampling including a compositional analysis of the pre-flash pressurized condensate routed to these storage tanks and a sales oil analysis to determine RVP and API gravity. The sample shall be taken from the sample port directly upstream of the VRT. Testing shall be in accordance with the guidance contained in PS Memo 05-01. Results of testing shall be used to determine a site- specific emission factors for VOC, benzene, toluene, ethylbenzene, xylenes, n-hexane, and 2,2,4-trimethylpentane using Division approved methods. Results of site-specific sampling and analysis shall be submitted to the Division as part of the self-certification and used to demonstrate compliance with the emissions factors chosen for this emissions point. 25. Point 001, 002, 003, 004: Within ninety (90) days of commencement of operation, the owner or operator shall demonstrate compliance with opacity standards, using EPA AIRS ID: 123/9DDF Page 6 of 13 "a. ^topAv olor.;_ Depa nens of Piebli Health and Environment 'Air Pollution Control Division Method 22 ti.44- -. - in - �,. Inc °°-a-nce s;- Asible 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) 26. Point 004: Within ninety (90) days of commencement of operation, the operator shall complete an initial site specific extended gas analysis of the natural gas vented from this emissions unit in order to verify the VOC, benzene, toluene, ethylbenzene, xylenes, n- hexane, and 2,2,4-trimethylpentane content (weight fraction) of this emission stream. Results of testing shall be used to calculate site-specific emission factors for the pollutants 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 the emissions factors established through this initial testing are less than or equal to, the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If any site specific emissions factor developed through this sampling and analysis is greater than the emissions factors established in the permit application and "Notes to Permit Holder", the operator shall submit a request for permit modification to update emissions factors and emissions limits specified in this permit to the Division within 60 days. Periodic Testing Requirements 27. Points 003, 004: On a daily basis, the owner or operator shall demonstrate compliance with opacity standards, using EPA Method 22 to determine the presence or absence of visible emissions during daily flare monitoring as specified in the most recent O&M Plan. (Reference: Regulation No. 7, Section XVII.A.II) 28. Point 004: On an annual basis, the operator shall complete a site specific extended gas analysis 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 site-specific emission factors for the pollutants referenced above (in units of lb/MMSCF gas vented) using Division approved methods. Emission factors established through this periodic testing shall be less than or equal to, the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If the site specific emissions factor developed through this sampling and analysis is greater than the emissions factor established in the permit application and "Notes to Permit Holder" the operator shall submit to the Division within 60 days, a request for permit modification to update emissions factors and emissions limits specified in this permit. The owner or operator shall continue to use the emissions factors established in the permit application and "Notes to Permit Holder" to calculate actual emissions and demonstrate compliance with the emissions limits specified in this permit unless a modification is submitted to the Division. Records of site-specific sampling and emissions factor analysis shall be recorded and maintained by the operator and made available to the Division for inspection upon request. ADDITIONAL REQUIREMENTS 29. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, I I.C) a. Annually by April 30th whenever a significant increase in emissions occurs as follows: AIRS ID: 123/9DDF Page 7 of 13 olor Depa en . P •Ii Health and Environment it Pollution Control Division Fora a $.- a �`a� 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 NOX 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. 30. 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 31. 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. 32. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section III.G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self-certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization. Details for obtaining final authorization to operate are located in the Requirements to Self- Certify for Final Authorization section of this permit. AIRS ID: 123/9DDF Page 8 of 13 olor Depa • en P ' li VHealth and Environment it Pollution Control Division 33. This permit i u. m fe anc- t y an mpleteness 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. 34. 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. 35. 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. 36. 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. 37. 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: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Kerr-McGee Oil and Gas Onshore LP AIRS ID: 123/9DDF Page 9 of 13 olor. Depa en : P .li 'Health and Environment it Pollution Control Division Notes to Permit Holder me o ' '` •e "'"'' an Via: 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°/02FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s)operate at the permitted limitations. Uncontrolled Emission Are the Controlled AIRS Rate emissions Emission Rate Point Pollutant CAS# (Ib/yr) reportable? (Ib/yr) Benzene 71432 176 No 9 001 n-Hexane 110543 1571 Yes 79 Benzene 71432 34 No 2 n-Hexane 110543 302 Yes 15 002 Toluene 108883 92 No 5 Xylenes 1330207 50 No 3 Benzene 71432 5174 Yes 259 n-Hexane 110543 29971 Yes 1499 003 Toluene 108883 6048 Yes 302 Ethylbenzene 100414 1411 Yes 71 Xylenes 1330207 3763 Yes 188 Benzene 71432 16007 Yes 800 n-Hexane 110543 212698 Yes 10635 004 Toluene 108883 16124 Yes 806 Ethylbenzene 100414 721 Yes 36 Xylenes 1330207 5595 Yes 280 AIRS ID: 123/9DDF Page 10 of 13 olor Depa, en ,f P li Health and Environment it Pollution Control Division 5) The emission level di p _ b folio ission factors: Point 001: Emission Factors Uncontrolled Pollutant lb/BBL Source Condensate Throughput VOC 0.428 ProMax n-Hexane 0.0187 ProMax Benzene 0.0021 ProMax Toluene 0.0021 ProMax Ethylbenzene 0.00039 ProMax Xylenes 0.0010 ProMax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. Point 002: Emission Factors - Uncontrolled Pollutant lb/BBL loaded Source VOC 0.236 CDPHE Benzene 0.00041 CDPHE n-Hexane 0.0036 CDPHE Toluene 0.0011 ProMax Xylenes 0.0006 ProMax Note: State-approved VOC, benzene, and n-hexane emission factors from PS Memo 14-02. Toluene and xylene emission factors calculated by multiplying VOC emission factor by weight ratio of HAP from ProMax working and breathing emission stream. Point 003: Emission Factors Uncontrolled Pollutant Source Ib/BBL Condensate Throughput NOx(Ib/lbVOC) 0.0037 CDPHE CO (lb/lbVOC) 0.0094 CDPHE VOC 6.730 ProMax n-Hexane 0.446 ProMax Benzene 0.077 ProMax Toluene 0.090 ProMax Ethylbenzene 0.021 ProMax Xylenes 0.056 ProMax 2,2,4-TMP 0.031 ProMax Note: The controlled emissions for this point are based on the flare control efficiency of 95%. AIRS ID: 123/9DDF Page 11 of 13 ill olorl. Depa en • P^W.Ii Health and Environment it Pollution Control Division Point 004: Weight Fraction Emission Factors Pollutant of Gas (%) Uncontrolled (Ib/MMscf) Source NOx(Ib/MMBTU) --- 0.138 TCEQ CO (Ib/MMBTU) --- 0.28 TCEQ VOC 15.5 8361 Eng. Est. Benzene 0.0821 44.72 Eng. Est. Toluene 0.0827 45.05 Eng. Est. Ethylbenzene 0.0037 2.02 Eng. Est. Xylenes 0.0287 15.63 Eng. Est. n-hexane 1.0910 594.29 Eng. Est. Note: The controlled emissions for this point are based on the flare control efficiency of 95%. TCEQ combustion emission factors were used instead of the APCD Ib/IbVOC emission factors (as used for point 003) to account for the large amount of non-VOC hydrocarbon combustion associated with this point. 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) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, Benzene, Toluene, n-Hexane, total HAPs NANSR Synthetic Minor Source of: VOC 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 XXXXXX AIRS ID: 123/9DDF Page 12 of 13 „,,,„,,„, ,.,„:.,.,,,, ,_, II olora Depa . en f Pfi li Health and Environment BVit Pollution Control Division 60 ii 0,4 .,,,,,.. 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: 123/9DDF Page 13 of 13 Division Information Engineer: Christopher Kester Control Engineer: Stefanie Rucker Review Date: 09/21/2015 Application Date: 08/21/2015 Facility Identifiers Permit No. 15WE0875 Potentially located in ozone nonattainment area AIRs County# 123 'Weld Facility# 9DDF Facility Type: exploration and production facility ❑� Located in the 8-hour non-attainment area? O True Minor Synthetic Minor for: f✓ VOC E NOx r CO Administrative Information Company Name: Kerr-McGee Oil and Gas Onshore Source Name: J-Sand North Test Facility Source Location: SE S36 T1 N R63W SIC: 1311 Address 1: Kerr-McGee Oil and Gas Onshore Mailing Address Address 2: P.O. Box 173779 ty,State Zip: Denver, CO Name: David Steger Person To Phone: 720-929-6075 Contact Fax: Email: David.Steger@anadarko.com 'Requested Action Self Certification Required? Yes Issuance Number: 1 Source Description: Oil and gas exploration and production facility known as the J-Sand North Test Facility, located in the SE S36 Ti N R63W,Weld County, Colorado. Point Name Type Control Action Newly 001 TK01 -TK02 Condensate Tanks Flare reported source Newly 002 TL-01 Loadout Flare reported source Newly Using the"Condensate Tanks" 003 ECD-VRT Condensate Tanks Flare reported Selection because operator is source modeling this point with a liquids Newly 004 PRFL-01 Separator Venting Flare reported source 001 Two(2)300 bbl condensate storage tanks.Emissions from the tanks are routed to an enclosed combustor that achieves a minimum control efficiency of 95% Requsted Throughput 84000 bbl Control Flare Efficiency 95.00%i Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.4282 lb/bbl 17.98 tpy 0.9 tpy Promax Simulation using Benzene 0.0021 lb/bbl 176.4 lb/yr 8.82 lb/yr pressurized liquids sample Toluene 0.0021 lb/bbl 176.4 lb/yr 8.82 lb/yr from a representative well. Ethylbenzene 0.00039 lb/bbl 32.76 lb/yr 1.638 lb/yr Site specific sampling will be Xylenes 0.001 lb/bbl 84 lb/yr 4.2 lb/yr required in permit n-Hexane 0.0187 Ib/bbl 1570.8 lb/yr 78.54 lb/yr CO 0.0094 lb/lbVOC 0.16905336 tpy 0.169053 tpy State Condensate Flare NOx 0.0037 Ib/IbVOC 0.06654228 tpy 0.003327 tpy Emission Factors 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. 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 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 each tank is less than 19,800 gallons(471 bbl) NSPS OOOO:for storage vessels in the natural gas production,transmission,and processing segments. This source is not subject because each tank 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 requirements for condensate tanks since it is located in a non-attainment area.) XVII.C STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... (Applicant is not currently subject to this since actual uncontrolled emissions are less than 20 tpy of VOC.) 002 Truck loadout of condensate.Emissions from the loadout are routed to an enclosed combustor that achieves a minimum control efficiency of 95% Calculations Annual requested Throughput 84000 BBL/yr 3528000 gal/yr Control: Flare Efficiency: 95.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.236000 lb/bbl 9.9 tpy 0.5 tpy State Default Emission Benzene 0.000410 lb/bbl 34.4 lb/yr 1.7 lb/yr Factors for Condensate n-Hexane 0.003600 lb/bbl 302 lb/yr 15 lb/yr Loadout Toluene 0.001140 lb/bbl 96 lb/yr 5 lb/yr Using VOC/HAP ratio from Ethylbenzene 0.000215 lb/bbl 18 lb/yr 1 lb/yr W&B emission estimates Xylenes 0.000569 lb/bbl 48 lb/yr 2 lb/yr from Promax simulation for 224 TMP 0.000555 lb/bbl 47 lb/yr 2 lb/yr Tanks/VRT CO 0.009400 Ib/lbVOC 0.09 tpy 0.09 tpy State Condensate Flare NOx 0.003700 lb/IbVOC 0.04 tpy 0.04 tpy Emission Factors 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.1.1 003 One(1)vapor recovery tower to provide third stage of separation before storage tanks.Emissions from the VRT are routed to an enclosed flare that acheives a minimum control efficiency of 95%. Requsted Throughput 67200 bbl Control Flare Efficiency 95.00%i Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 6.73 lb/bbl 226.1 tpy 11.3 tpy Benzene 0.077 lb/bbl 5174.4 lb/yr 258.72 lb/yr Promax Simulation using Toluene 0.09 lb/bbl 6048 lb/yr 302.4 lb/yr pressurized liquids sample from Ethylbenzene 0.021 lb/bbl 1411.2 lb/yr 70.56 lb/yr a representative well.Site Xylenes 0.056 lb/bbl 3763.2 lb/yr 188.16 lb/yr specific sampling will be n-Hexane 0.446 lb/bbl 29971.2 lb/yr 1498.56 lb/yr required in permit 224 TMP 0.031 lb/bbl 2083.2 lb/yr 104.16 lb/yr CO 0.0094 lb/IbVOC 2.1256032 tpy 2.125603 tpy State Condensate Flare Emission NOx 0.0037 lb/IbVOC 0.8366736 tpy 0.836674 tpy Factors Regulatory Review 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 AQCC Regulation 2 Section I.A applies to all emission sources. "No person, wherever located, shall cause or allow the emission of odorous 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 Process flare to temporarily burn separator and heater treater gas.The flare acheives a minimum control 004 efficiency of 95%. 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) 357.9 MMscf/yr 40856.16438 scf/hr MW 20.6 Ib/Ib-mol 0.980547945 MMscf/d mole% MW Ibx/Ibmol mass fraction lb/hr Ib/yr tpy Helium 0.0000 4.0026 0.000 0.00000 0.00 0.00 0.00 CO2 3.0500 44.01 1.342 0.06516 144.70 1267575.09 633.79 N2 0.6600 28.013 0.185 0.00898 19.93 174592.69 87.30 methane 79.1000 16.041 12.688 0.61594 1367.81 11982030.22 5991.02 ethane 10.8200 30.063 3.253 0.15790 350.65 3071723.12 1535.86 propane 3.6900 44.092 1.627 0.07898 175.39 1536415.41 768.21 isobutane 1.5000 58.118 0.872 0.04232 93.98 823236.10 411.62 n-butane 0.0000 58.118 0.000 0.00000 0.00 0.00 0.00 isopentane 0.0000 72.114 0.000 0.00000 0.00 0.00 0.00 n-pentane 0.6100 72.114 0.440 0.02135 47.42 415405.18 207.70 cyclopentane 0.0000 70.13 0.000 0.00000 0.00 0.00 0.00 n-Hexane 0.2600 86.18 0.224 0.01088 24.15 211593.50 105.80 cyclohexane 84.16 0.000 0.00 0.00 0.00 Other hexanes 86.18 0.000 0.00 0.00 0.00 heptanes 100.21 0.000 0.00 0.00 0.00 methylcyclohexane 98.19 0.000 0.00 0.00 0.00 224-TMP 114.23 0.000 0.00 0.00 0.00 Benzene 78.12 0.000 0.00082 1.82 15971.03 7.99 Toluene 92.15 0.000 0.00083 1.84 16087.75 8.04 Ethylbenzene 106.17 0.000 0.00004 0.08 719.77 0.36 Xylenes 106.17 0.000 0.00029 0.64 5583.05 2.79 C8+Heavies 118 0.000 0.00 0.00 0.00 99.6900 VOC mass fracf 0.156 Total VOC(Uncontrolled) 1512.51 1.00348 Notes Mole%,MW,and mass fractions from anticipated analysis of gas to be flared based on average of previously drilled J-sand wells in the DJ basin.Site Specific sampling will be required in permit. 15WE0875.CP1.xlsm Process flare to temporarily burn separator and heater treater gas.The flare acheives a minimum control 004 efficiency of 95%. Flaring Information Gas Heating Value 1215 Btu/scf Throughput 434848.5 MMBtu/yr Overall Control 95.00% Combustion emission factor source: TCEQ flarin emission factor 0.138 alb NOX/MMBtu 0.28 llb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 8452 lb/MMscf 422.61 lb/MMscf 1512.5 tpy 75.6 tpy Gas Analysis Nox 0.14 lb/MMBTU 0.14 lb/MMBTU 30.0 tpy 30.0 tpy AP-42 CO 0.28 lb/MMBTU 0.28 lb/MMBTU 60.9 tpy 60.9 tpy AP-42 Benzene 44.62 lb/MMscf 2.23 lb/MMscf 15971 lb/yr 799 lb/yr Gas Analysis n-Hexane 591.21 lb/MMscf 29.5604 lb/MMscf 211594 lb/yr 10580 lb/yr Gas Analysis Toluene 44.950 lb/MMscf 2.2475 lb/MMscf 16088 lb/yr 804 lb/yr Gas Analysis Xylenes 15.599 lb/MMscf 0.7800 lb/MMscf 5583 lb/yr 279 lb/yr Gas Analysis Ethylbenzene 2.011 lb/MMscf 0.1006 lb/MMscf 720 lb/yr 36 lb/yr Gas Analysis 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.' 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O 37.. �" a L v) ill W N o U c 7 a E W W U U o . ; i 7 a I w p I a 7 I °� cc, y v o c p l d O If) a U ro 0 o a 0 5 0 0 ez ® ❑ x U U Y > ¢ ,o c c,2 O 00 ro Z ° G .-1 U F U C W o 2 U a[i a) " ❑ > LL 0.1 -C cd .J o.co Y U ❑ ® U ® ❑ C U cJ L �D .) Ca W n ® cn w CI) 1'.L.ki L V��..} '.30 Avc9 CDP"E General APEN - Form APCD-200 co Air Pollutant Emission Notice (APEN) and Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. There may be a more specific APEN for your source (e.g. paint booths, mining operations,engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five(5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: ' SwCo�� AIRS ID Number: j23 /'1DD F/003 [Leave blank unless APCD has already assigned a permit l/and AIRS ID] Section 1 - Administrative Information Company Name': Kerr-McGee Oil and Gas Onshore, LP Site Name: J-Sand North Test Facility Site Location Site Location: SE S36 T1 N R63W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) PO Box 173779 Denver, CO Permit Contact: David Steger Phone Number: 720-929-6075 Portable Source Home Base: E-Mail Address: david.steger@anadarko.com 'Please use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD. Any changes will require additional paperwork. .COLORADO Form APCD-2OO-General APEN -Revision 7/2015 1 �'pw N6Fn vw mm, 1 } — Permit Number: W V� � AIRS ID Number: / / 1 � G �23 �D� 003 [Leave blank unless APCD has already assigned a permit It and AIRS ID] Section 2- Requested Action ❑✓ NEW permit OR newly-reported emission source(check one below) ❑✓ STATIONARY source ❑ PORTABLE source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership2 ❑ Other (describe below) -OR- ❑ APEN submittal for update only(Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - • Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit(PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Requesting facility-wide construction permit: vapor recovery tower(VRT) 2 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: Provide 3rd stage of gas/liquid separation before tanks Manufacturer: Model No.: Serial No.: Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 4/1/2016 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: .COLORADO Form APCD-200- General APEN - Revision 7/2015 2 or Permit Number: I S i .C) 7-S. AIRS ID Number: 123 i 9DDF-/ Do 3 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 4 - Processing/Manufacturing Processing/Manufacturing Information Et Material Use ❑Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Actual Annual Requested Annual Description Rate Amount Permit Limit3 (Specify Units) (Specify Units) (Specify Units) Condensate Throughput 67200 bbl/yr Material Consumption: Flash gas Finished Product(s): 3Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.001997, -104.380614 ❑ Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height' Operator Temp. Flow Rate ." Velocit Above Ground Level Y Stack ID No ('F) (ACFM)_ (ft/sec) (Feet) • ECD-VRT 25 Indicate the direction of the stack outlet: (check one) ❑ Upward LI Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ✓❑ Circular Interior stack diameter(inches): 48" ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): COLORADO Form APCD 200 General APEN Revision 7/2015 3 """ Permit Number: I _5\4 -Gov-Ts- AIRS ID Number: R-1 /9DDF/ 003 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 6 - Combustion Equipment Et Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel-burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit3 (MMBTU/hr) (Specify Units) (Specify Units) From what year is the actual annual fuel use data? Indicate the type of fuel used': ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑� Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other(describe): Heating value(give units): 3 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 4 If fuel heating value is different than the listed assumed value,please provide this information in the"Other"field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ® Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency(%reduction): Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP (PM) PM10 PM2.5 SOX NOX CO VOC Enclosed Flare 95 Other: COLORa DO Form APCD 200 General APEN Revision 7/2015 4 Av Permit Number: ( W C(%-3-S' AIRS ID Number: )2,3 / f DDF/ DU3 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7(continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Requested Annual Permit Uncontrolled Factor Actual Annual Emissions a Emission Emission Limit(s) Pollutant Source Factor (specify Units) (AP-42,Mfg. Uncontrolled Controlled5 Uncontrolled Controlled etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP(PM) PM1a PM2.5 SOS NOS 0.0037 lb/IbVOC' APCD -- 0.837 CO 0.00941b/IbVOC' APCD -- 2.126 • VOC 6.730 lb/bbl i ProMax 226.13 i 11.31 Other: 3 Requested values wilt become permit limitations. Requested limit(s)should consider future process growth. 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants(e.g. HAP- hazardous air pollutant)emissions equal to or greater than 250 ®Yes ❑ No lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled Overall Emission Factor CAS Emission Actual Actual C, )Lc>��cr Chemical Name Control Source 5 Number Efficiency Factor (AP-42,Mfg.etc) Emissions Emissions cr a pl`ci to (specify units) .N y�N}-fy .0 ai Ty iI Benzene 95 0.077 ". ProMax 2.58 ' 0.13 - w/oc/1 S Toluene 95 0.090— ProMax 3.04 -- 0.15 -- E-Benzene 95 0.021 - ProMax 0.69 ' 0.03 -' Xylene 95 0.056- ProMax 1.87 - 0.09 N-Hexane 95 0.446 ' ProMax 15.00- 0.75 224-TMP 95 0.031 .-- ProMax 1.03, 0.05 - 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. SOkACL_ \'V— no .iSe-'7- Siro.r)-eCk o PCCW-1 % Form APCD-200-General APEN - Revision 7/2015 5 I �� cocoeaoo rv"iNar�::o >c Permit Number: I S W U)K7-5 AIRS ID Number: 113 / 9DDR/ (j�3 [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. it 936 Zo5 Signature of Legally Authorized Person (not a vendor or consultant) Date David Steger HSE Representative Name (please print) Title Check the appropriate box to request a copy of the: Engineer's Preliminary Analysis conducted Draft permit prior to issuance O✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. II it Send this form along with$152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303) 692-3175 or(303)692-3148 APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 www.colorado.gov/pacific/cdphe/air-permits Telephone: (303)692-3150 COLORADO Form APCD-200-General APEN - Revision 7/2015 6 I A� °`H�aln 6LnMmm•n, SEP 30 20i5 AI'C'D General APEN — Form APCD-200 Air Pollutant Emission Notice (APEN) and CO Application for Construction Permit All sections of this APEN and application must be completed for both new and existing facilities, including APEN updates. An application with missing information may be determined incomplete and may be returned or result in longer application processing times. You may be charged an additional APEN fee if the APEN is filled out incorrectly or is missing information and requires re-submittal. There may be a more specific APEN for your source(e.g. paint booths, mining operations, engines, etc.). A list of specialty APENs is available on the Air Pollution Control Division (APCD)website at www.colorado.gov/pacific/cdphe/air-permits. This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Permit Number: ' S W AIRS ID Number: l 23 / / [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 1 -Administrative Information Company Name': Kerr-McGee Oil and Gas Onshore, LP Site Name: J-Sand North Test Facility Site Location Site Location: SE S36 T1 N R63W County: Weld NAICS or SIC Code: 1311 Mailing Address: (Include Zip Code) PO Box 173779 Denver, CO Permit Contact: David Steger Phone Number: 720-929-6075 Portable Source Home Base: E-Mail Address: david.steger@anadarko.com 'Please use the full,legal company name registered with the Colorado Secretary of State.This is the company name that will appear on all documents issued by the APCD.Any changes will require additional paperwork. COLORADO Form APCD-200- General APEN - Revision 7/2015 1 I elf „2T,T,T`.° . SwGo�-7s Permit Number: AIRS ID Number: Z J / 1DO�/ U(J CI [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 2- Requested Action El NEW permit OR newly-reported emission source(check one below) O STATIONARY source ❑ PORTABLE source -OR- ❑ MODIFICATION to existing permit(check each box below that applies) ❑ Change fuel or equipment ❑ Change company name ❑ Add point to existing permit ❑ Change permit limit ❑ Transfer of ownership2 ❑ Other(describe below) -OR- ❑ APEN submittal for update only (Please note blank APENs will not be accepted) -ADDITIONAL PERMIT ACTIONS - Limit Hazardous Air Pollutants(HAPs)with a federally-enforceable limit on Potential To Emit (PTE) ❑ APEN submittal for permit exempt/grandfathered source Additional Info Et Notes: Requesting facility-wide construction permit: production flare 2 For transfer of ownership,a completed Transfer of Ownership Certification Form (Form APCD-104)must be submitted. Section 3 - General Information General description of equipment and purpose: Temporarily burn separator & heater-treater gas Manufacturer: Model No.: Serial No.: Company equipment Identification No. (optional): For existing sources, operation began on: For new or reconstructed sources, the projected start-up date is: 4/1/2016 ❑ Check this box if operating hours are 8,760 hours per year; if fewer, fill out the fields below: Normal Hours of Source Operation: 24 hours/day 7 days/week 52 weeks/year Seasonal use percentage: Dec-Feb: Mar-May: June-Aug: Sept-Nov: .COLORADO Form APCD-200- General APEN - Revision 7/2015 2 I �� , Permit Number: 5\4C-_0%•7-S- AIRS ID Number: IZS /9PPF/ OULj [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 4 - Processing/Manufacturing Information Et Material Use ❑✓ Check box if this information is not applicable to source or process From what year is the actual annual amount? Design Process Actual Annual Requested Annual Description Rate Amount Permit Limit3 (Specify Units) (Specify Units) (Specify Units) Produced Gas 357.9 MMscf/yr Material Consumption: Finished Product(s): 3Requested values will become permit limitations. Requested limit(s)should consider future process growth. Section 5 - Stack Information Geographical Coordinates (Latitude/Longitude or UTM) 40.001997, -104.380614 ❑Check box if the following information is not applicable to the source because emissions will not be emitted from a stack. If this is the case, the rest of this section may remain blank. Discharge Height • Operator Temp Flow Rate Velocity Above Ground Level, Stack ID No cFj (ACFM) (ft/secj s - . (Feet) PRFL-01 Indicate the direction of the stack outlet: (check one) ❑ Upward ❑ Downward ❑ Upward with obstructing raincap ❑ Horizontal ❑ Other(describe): Indicate the stack opening and size: (check one) ✓❑ Circular Interior stack diameter(inches): ❑ Square/rectangle Interior stack width (inches): Interior stack depth (inches): ❑ Other(describe): --- CD LDRADO Form APCD-200- General APEN - Revision 7/2015 3 I A® Permit Number: ( SW CCA51-S- AIRS ID Number: "Z3 / 5DPF-1 OOLI [Leave blank unless APCD has already assigned a permit N and AIRS ID] Section 6 - Combustion Equipment & Fuel Consumption Information ❑ Check box if this information is not applicable to the source (e.g. there is no fuel-burning equipment associated with this emission source) Design Input Rate Actual Annual Fuel Use Requested Annual Permit Limit3 (MMBTU/hr) (Specify'Units) (Specify Units) From what year is the actual annual fuel use data? Indicate the type of fuel used4: ❑ Pipeline Natural Gas (assumed fuel heating value of 1,020 BTU/SCF) ❑■ Field Natural Gas Heating value: BTU/SCF ❑ Ultra Low Sulfur Diesel (assumed fuel heating value of 138,000 BTU/gallon) ❑ Propane (assumed fuel heating value of 2,300 BTU/SCF) ❑ Coal Heating value: BTU/lb Ash Content: Sulfur Content: ❑ Other(describe): Heating value(give units): 3 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 4 I fuel heating value is different than the listed assumed value,please provide this information in the"Other"field. Section 7 - Criteria Pollutant Emissions Information Attach all emission calculations and emission factor documentation to this APEN form. Is any emission control equipment or practice used to reduce emissions? ®Yes ❑ No If yes, please describe the control equipment AND state the overall control efficiency(%reduction): Pollutant Control Equipment Description Overall Control Efficiency (%reduction in emissions) TSP(PM) PMio PM2.s SOX NOx CO VOC Enclosed Production Flare 95 Other: 4 A ©© �co�oRano Form APCD 200 General APEN Revision 7/2015 v Permit Number: ( J W e bc0 S- AIRS ID Number: /MIN / oo [Leave blank unless APCD has already assigned a permit#and AIRS ID] Section 7(continued) From what year is the following reported actual annual emissions data? Use the following table to report the criteria pollutant emissions from source: (Use the data reported in Sections 4 and 6 to calculate these emissions.) Emission Uncontrolled Requested Annual Permit Factor Actual Annual Emissions 3 Pollutant Emission Source Emission Limit(s)Factor 3 Mfg. Uncontrolled Controlled' Uncontrolled Controlled (Specify Units) etc) (Tons/year) (Tons/year) (Tons/year) (Tons/year) TSP (PM) PM55 PMz.5 Sox NO), 0.138 lb/MMBtu TCEQ - 30.0 CO 0.28 Ib/MMBtu. TCEQ - 60.9 VOC 8361 Ib/MMSCF-- Gas analysis 1496.2- 74.8 -- Other: 3 Requested values will become permit limitations. Requested limit(s)should consider future process growth. 5Annuat emission fees will be based on actual controlled emissions reported. If source has not yet started operating, leave blank. Section 8 - Non-Criteria Pollutant Emissions Information Does the emissions source have any uncontrolled actual emissions of non-criteria pollutants (e.g. HAP- hazardous air pollutant)emissions equal to or greater than 250 ®Yes ❑ No lbs/year? If yes, use the following table to report the non-criteria pollutant(HAP)emissions from source: Uncontrolled Uncontrolled Controlled CAS Overall Emission Emission Factor Actual Actual Number Chemical Name Control Factor Source Emissions Emissions' Efficiency (specify units) (AP-42,Mfg.etc) (lbs/year) (lbs/year) Benzene 95 44.72 Ib/MMSCF'Engineering Estimate 16007 - 800 Toluene 95 45.05 Ib/MMSCF.-Engineering Estimate 16124 806 Ethylbenzene 95 2.02 Ib/MMSCF.-Engineering Estimate 721.4 - 36.07 Xylenes 95 15.63 Ib/MMSCF- Engineering Estimate 5595 ' 280 ' n-Hexane 95 594 Ib/MMSCF.-Engineering Estimate 212698 r 10635 5Annual emission fees will be based on actual controlled emissions reported. If source has not yet started operating,leave blank. .3 LA(C.e Hof jet COLORADO Form APCD-200- General APEN - Revision 7/2015 5 1 „t�eE vow , Permit Number: 15 W C6 C6- S AIRS ID Number: Z� / I DDF/COI [Leave blank unless APCD has already assigned a permit 1 and AIRS ID] Section 9 - Applicant Certification I hereby certify that all information contained herein and information submitted with this application is complete, true and correct. - of Signature of Legally Authorized Person (not a vendor or consultant) Date David Steger HSE Representative Name(please print) Title Check the appropriate box to request a copy of the: ✓E Engineer's Preliminary Analysis conducted �✓ Draft permit prior to issuance E✓ Draft permit prior to public notice (Checking any of these boxes may result in an increased fee and/or processing time) This emission notice is valid for five (5)years. Submission of a revised APEN is required 30 days prior to expiration of the five-year term, or when a reportable change is made (significant emissions increase, increase production, new equipment, change in fuel type, etc). See Regulation No. 3, Part A, II.C. for revised APEN requirements. Send this form along with$152.90 to: For more information or assistance call: Colorado Department of Public Health and Environment Small Business Assistance Program Air Pollution Control Division (303) 692-3175 or(303)692-3148 APCD-SS-B1 4300 Cherry Creek Drive South Or visit the APCD website at: Denver, CO 80246-1530 www.colorado.gov/pacific/cdphe/air-permits Telephone: (303) 692-3150 COLORADO Form APCD-2OO- General APEN - Revision 7/2015 6 I �� Hello