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Home My WebLink About20161650.tiff C O P H E COLORADO COff Department of Public • Health Er Environment Dedicated to protecting and improving the health and environment of the people of Colorado RECEIVED Weld County - Clerk to the Board 1150 0 St MAY 1 9 2016 PO Box 758 Greeley, CO 80632 WELD COUNTY COMMISSIONERS May 16, 2016 Dear Sir or Madam: On May 18, 2016, the Air Pollution Control Division will begin a 30-day public notice period for Carrizo Oil Et Gas, Inc. - Bringelson Ranch 13-20 Multi-pad. 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, r' 1 ` Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure 2016-1650 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe John W. Hickenlooper, Governorn LarpA Wo lk�M161,MSpy, Executivy� ctor and Chief Medical Officer A CDPHE Air Pollution Control Division 17.1 CO Notice of a Proposed Project or Activity Warranting Public ' Comment Website Title: Carrizo Oil Et Gas, Inc. - Bringelson Ranch 13-20 Multi-pad - Weld County Notice Period Begins: May 18, 2016 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: Carrizo Oil Et Gas, Inc. Facility: Bringelson Ranch 13-20 Multi-pad Oil and gas well production facility SWNW of Section 20 of T9N R58W Weld County The proposed project or activity is as follows: Applicant proposes to construct and operate an oil Et gas well production facility, including crude oil storage, produced water storage, crude oil loadout to tank trucks, and flaring of gas when the sales gas pipeline is not available. 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): • the source is requesting a federally enforceable limit on the potential to emit in order to avoid other requirements; and • permitted emissions exceed public notice threshold values in Regulation No. 3, Part B, Section III.C.1.a (i.e., 50 tpy in an attainment area) 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 Permits 16WE0227, 16WE0230, and 16WE0231 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: Andy Gruel 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 1AV; 5"t;,',7"=:. : HaxLh kY ni CDPHE Construction Permit CO %' Air Pollution Control Division rw Permit number: 16WE0227 Issuance: 1 Date issued: Issued to: Carrizo Oil &t Gas, Inc. Facility Name: Bringelson 13-20 Multi-pad Plant AIRS ID: 123-9E56 Physical Location: SWNW Section 20 T9N R58W County: Weld County General Description: Well Production Facility Equipment or activity subject to this permit: Facility AIRS Emissions Control Equipment Point Equipment Description Description ID TANKS 001 Nineteen (19) 400-barrel fixed roof storage Enclosed Flare vessels used to store crude oil. 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 the specific 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 of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permitting- notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at www.colorado.gov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section 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 Storage Tank Version Syn Minor 2015-1 Page 1 of 7 r 1 h t da o';,ssuanc-...•f this construction permit or the date on which such onst on cti " sche `I =d 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. (Regulation Number 3, Part B, Section 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. (Regulation Number 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. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation Number 3, Part B, Section II.A.4.) Annual Limits: Facility AIRS Tons per Year Emission Equipment ID Point PM2.5 NO, VOC CO Type TANKS 001 --- --- 9.0 2.1 Point Note: 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 not exceed 8.0 tons per year. Facility-wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility-wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation Number 3, Part B, Section III.E.) Facility AIRS Control Device Pollutants Equipment ID Point Controlled TANKS 001 Enclosed Flare VOC and HAP PROCESS LIMITATIONS AND RECORDS 8. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Regulation Number 3, Part B, II.A.4.) 4 CDPHE ; COLORADO CO trr' ! Air Poitution Control Division Dinar,,,, 4bic1fzstt,:,s_•,≤gorr Page 2 of 7 ,es Dis Facility AIRS Process Parameter Annual Limit Equipment ID Point TANKS 001 Crude Oil throughput 296,601 barrels Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. STATE AND FEDERAL REGULATORY REQUIREMENTS 9. The permit number and ten digit AIRS ID number assigned by the Division (i.e., 123/9E56/001) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, Section III.E.) (State only enforceable) 10. This source is subject to the odor requirements of Regulation Number 2. (State only enforceable) 11. The combustion device covered by this permit is subject to Regulation Number 7, Section XVII.B.2. 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. This flare must be equipped with an operational auto-igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device; • All combustion devices 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. 12. The storage tank covered by this permit is subject to the emission control requirements in Regulation Number 7, Section XVII.C.1. The owner or operator shall 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 except where the combustion device has been authorized by permit prior to May 1, 2014. The source shall follow the inspection requirements of Regulation Number 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 requirement must be met within 90 days of the date that the storage tank commences operation. 13. The storage tanks covered by this permit are subject to the venting and Storage Tank Emission Management System ("STEM") requirements of Regulation Number 7, Section XVII.C.2. OPERATING Et MAINTENANCE REQUIREMENTS 14. Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (OEM) 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) Gph"E COLORADO O 7 Air Pollution Control Division re,, I,Jet t Page 3 of 7 a f COM G D PG Initial Testing Requirements 15. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, 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 minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) Periodic Testing Requirements 16. This source is not required to conduct periodic testing, unless otherwise directed by the Division or other state or federal requirement. ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Regulation Number 3, Part A, II.C.) • 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 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. • Whenever there is a change in the owner or operator of any facility, process, or activity; or • Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or • Whenever a permit limitation must be modified; or • No later than 30 days before the existing APEN expires. 18. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation Number 3, Parts C and D). 19. MACT Subpart HH - National Emission Standards for Hazardous Air Pollutants From Oil and Natural Gas Production Facilities major stationary source requirements shall apply to this stationary source at any such time that this stationary source becomes major solely by virtue of a relaxation in any permit limitation and shall be subject to all appropriate applicable requirements of Subpart HH. (Regulation Number 8, Part E, Subpart HH) GENERAL TERMS AND CONDITIONS 20. 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 4 COPHE COLORADO CO Air Pollution Control Division xu f .ac)1w :1,417,J117,en1 Page 4 of 7 Ak Ark la in �, m er Pa B, Sect n II.B. upon a request for transfer of ownership and the ‘ubmi o se "` nd th` =quired fee. 21. 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 Number 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. 22. 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. 23. 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. 24. 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. 25. 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. 26. 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: Andy Gruel, P.E. Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Carrizo Oil 8 Gas, Inc. Newly permitted synthetic minor facility. 41/4 corwe COLORADO Co Air Pollution Control Division ruts ,e.,g wio,",.„r Page 5 of 7 II Alk No -� - r . F • ;. th- this , it issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit. (Regulation Number 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: https://www.colorado.gov/pacific/cdphe/aqcc-regs 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. AIRS Uncontrolled Controlled Point Pollutant CAS# Emissions Emissions (lb/yr) (Ib/yr) Benzene 71432 3500 175 Toluene 108883 3107 156 Ethylbenzene 100414 360 18 001 Xylenes 1130207 838 42 n-Hexane 110543 21,725 1,086 2,2,4- 540841 1336 67 Trimethylpentane Note: All non-criteria reportable pollutants in the table above with uncontrolled emission rates above 250 pounds per year(lb/yr)are reportable and may result in annual emission fees based on the most recent Air Pollution Emission Notice. 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Uncontrolled Controlled CAS# Pollutant Emission Factors Emission Factors Source lb/bbl lb/bbl N0x N/A 0.025 AP-42 Chap 13.5 CO N/A 0.0136 AP-42 Chap 13.5 V0C 1.213 0.06065 EEtP Tanks 71432 Benzene 0.0118 0.00059 EEtP Tanks 108883 Toluene 0.0105 0.000525 EEtP Tanks 100414 Ethylbenzene 0.001214 0.0000607 EEtP Tanks 1330207 Xylene 0.00283 0.0001415 EEtP Tanks 110543 n-Hexane 0.07323 0.0036615 EEtP Tanks � E COLORADO CO tr Air Pollution Control Division ,,,,r-rv,%CI.�t,1 Heae:^;, „�rn,.',1 Page 6 of 7 6 A 4IT ; controlled Controlled •S# ' •o lut. i ion Factors Emission Factors Source lb/bbl lb/bbl 540841 2'2'4 0.00452 0.000226 EEtP Tanks Trimethylpentane Note: The controlled emissions factors 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 associated with this permit. For any questions regarding a specific expiration date call the Division at (303)-692-3150. 7) This permit fulfills the requirement to hold a valid permit reflecting the storage tank and associated control device per the Colorado Oil and Gas Conservation Commission rule 805b(2)(A) when applicable. 8) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC, HAPs (total, and n-hexane) PSD Synthetic Minor Source of: VOC MACT HH Area Source Requirements: Not Applicable 9) 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 CDP COLORADO co Air Pollution Control Division �':u Y,t ,I',1U !1 s.,.1 tan-win, Page 7 of 7 STATE OF COLORADO �/oF-co� COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT e/ AIR POLLUTION CONTROL DIVISION mac. TELEPHONE: (303)692-3150 Jw: *1816. CONSTRUCTION PERMIT PERMIT NO: 1 6WE0230 Issuance 1 DATE ISSUED: ISSUED TO: Carrizo Oil & Gas, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as Bringelson Ranch 13-20 Multi-pad, located in the SWNW of Section 20 of Township 9N Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID LOAD 001 Truck loadout of condensate. Emissions from the loadout are not controlled. 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 of the latter of commencement of operation or issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at https://www.colorado.gov/pacific/cdphe/other-air- permittinq-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source AIRS ID: 123/9E56 Page 1 of 7 Condensate Loadout TM Version 2012-1 i I p Co I do e p e o Public Health and Environment Air Pollution Control Division 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 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 5. 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 Equipment Point Emission Type ID VOC LOAD 001 15.0 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. M 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. PROCESS LIMITATIONS AND RECORDS 6. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) AIRS ID: 123/9E56 Page 2 of 7 , Co 4 do P p a9 e o Public Health and Environment li Air Pollution Control Division Process/Consumption Limits AIRS Process Parameter Annual Limit Point 001 Crude Oil Loading 296,601 BBL 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. 7. Condensate loading to truck tanks shall be conducted by submerged fill. (Reference: Regulation 3, Part B, III.E) STATE AND FEDERAL REGULATORY REQUIREMENTS 8. Visible emissions shall not exceed twenty percent (20%) opacity during normal operation of the source. During periods of startup, process modification, or adjustment of control equipment visible emissions shall not exceed 30% opacity for more than six minutes in any sixty consecutive minutes. Emission control devices subject to Regulation 7, Sections XII.C.1.d or XVII.B.1.c shall have no visible emissions. (Reference: Regulation No. 1, Section II.A.1. & 4.) 9. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 10. 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, I II.D.2): 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 at the facility (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 onsite loading equipment during loading operations to monitor compliance with above conditions. The inspections shall occur at least monthly. Each inspection shall be documented in a log available to the Division on request. 11. 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. OPERATING & MAINTENANCE REQUIREMENTS 12. This source is not required to follow a Division-approved operating and maintenance plan. AIRS ID: 123/9E56 Page 3 of 7 Co A do p e o Public Health and Environment Air Pollution Control Dmivision COMPLIANCE TESTING AND SAMPLING 13. This source is not required to comply with any testing and sampling requirements. ADDITIONAL REQUIREMENTS 14. 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 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. 15. Federal regulatory program requirements (i.e. PSD) 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 16. 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. 17. 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 AIRS ID: 123/9E56 Page 4 of 7 Co ado • p e o Public Health and Environment Air Pollution Control Division s�� a 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. 18. 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. 19. 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. 20. 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. 21. 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. 22. 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: Andy Gruel, P.E. Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Carrizo Oil & Gas, Inc. Newly permitted synthetic minor facility. AIRS ID: 123/9E56 Page 5 of 7 Co do a p t e o Public Health and Environment 6 Air Pollution Control Division Notes to Permit Holder at the time of this permit issuance: 1) The permit holder is required to pay fees for the processing time for this permit. An invoice for these fees will be issued after the permit is issued. The permit holder shall pay the invoice within 30 days of receipt of the invoice. Failure to pay the invoice will result in revocation of this permit (Reference: Regulation No. 3, Part A, Section VI.B.) 2) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application. These limits may be revised upon request of the owner or operator providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and complete application form must be submitted with a request for a permit revision. 3) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The owner or operator shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible, but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part II.E.1. of the Common Provisions Regulation. See: https://www.colorado.gov/pacific/cdphe/agcc-regs . 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 Point Pollutant CAS# (Ib/yr) reportable? Rate(lb/yr) Benzene 71432 291 Yes N/A 003 Toluene 108883 259 Yes N/A n-Hexane 110543 1,804 Yes N/A 5) The emission levels contained in this permit are based on the following emission factors: Emission Factors - Uncontrolled CAS Pollutant lb/BBL loaded Source VOC 0.100777 AP-42 71432 Benzene 0.000980 Eng. Calc. 108883 Toluene 0.000872 Eng. Calc. 110543 n-Hexane 0.006082 Eng. Calc. 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) = 3.4 psia M (vapor molecular weight) = 50 lb/lb-mol T(temperature of liquid loaded) = 529.67 °R The uncontrolled non-criteria reportable air pollutant (NCRP) emission factors were calculated by dividing the NCRP emission factor as modeled by E&P Tanks by the VOC emission factor as AIRS ID: 123/9E56 Page 6 of 7 lb IDCoiik do ' ;p e o Public Health and Environment Air Pollution Control Division modeled by E&P Tanks, and then multiplying that quotient by the total VOC loadout emission factor as calculated by the AP-42 Ch. 5-2 equation above. 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, HAPs (n-hexane, and total) PSD 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 9) A self certification form and guidance on how to self-certify compliance as required by this permit may be obtained online at: httc://www.colorado.gov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9E56 Page 7 of 7 STATE OF COLORADO OF�OCp COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT �`` AIR POLLUTION CONTROL DIVISION TELEPHONE: (303)692-3150 *1876 CONSTRUCTION PERMIT PERMIT NO: 1 61/Y E0231 Issuance 1 DATE ISSUED: ISSUED TO: Carrizo Oil & Gas, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas production facility, known as Bringelson Ranch 13-20 Multi-pad, located in the SWNW of Section 20 of Township 9N Range 58W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID One (1) flare (Manufacturer: Leed, Model: 25', Serial No: 80367) SEPARATOR 004 used to combust produced gas from five (5) separators during sales pipeline downtime situations. This is an open flare. 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 of the latter of commencement of operation or issuance of this permit, y submitting a Notice of Startup form to the Division for the equipment covered by this permit. The Notice of Startup form may be downloaded online at www.colorado.gov/pacific/cdphe/other-air-permittinq-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation Number 3, Part B, Section III.G.1. and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) of the latter of commencement of operation or issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. A self certification form and guidance on how to self- certify compliance as required by this permit may be obtained online at AIRS ID: 123/9E56 Page 1 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division www.colorado.gov/pacific/cdphe/air-permit-self-certification. (Regulation Number 3, Part B, Section 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. (Regulation Number 3, Part B, Section 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. (Regulation Number 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. EMISSION LIMITATIONS AND RECORDS 6. Emissions of air pollutants shall not exceed the following limitations. (Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Equipment ID Point NO. VOC CO Emission Type SEPARATOR 004 3.4 49.1 18.6 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 not exceed 8.0 tons per year. Facility-wide emissions of total hazardous air pollutants shall not exceed 20.0 tons per year. The facility-wide emissions limitation for hazardous air pollutants shall apply to all permitted emission units at this facility. Compliance with the annual limits, for both criteria and hazardous air pollutants, 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 actual emissions each month and keep a compliance record on site or at a local field office with site responsibility for Division review. 7. The emission points in the table below shall be operated and maintained with the emissions control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit. (Regulation No.3, Part B, Section III.E.) AIRS ID: 123/9E56 Page 2 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division Facility AIRS Pollutants Control Device Equipment ID Point Controlled SEPARATOR 004 Open flare VOC, HAP PROCESS LIMITATIONS AND RECORDS 8. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing 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 Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point SEPARATOR 004 Natural gas flaring 67.7 MMscf Compliance with the annual process 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. 9. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from each of the separators using a flow meter. The flow meter shall continuously measure flow rate and record total volumetric flow vented from each separator. The owner or operator shall use monthly throughput records to demonstrate compliance with the process limits contained in this permit and to calculate emissions as described in this permit. STATE AND FEDERAL REGULATORY REQUIREMENTS 10. The permit number and ten-digit AIRS ID number assigned by the Division (i.e,. 123- 9E56-004) shall be marked on the subject equipment for ease of identification. (Regulation Number 3, Part B, III.E.) (State only enforceable) 11. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. 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. (Reference: Regulation No. 1, Section II.A.1. &4.) 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. The open flare at this point has been approved as an alternative emissions control device under Regulation Number 7, Section XVII.B.2.e. The open flare must 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 open flare, or by other convenient AIRS ID: 123/9E56 Page 3 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division means approved by the Division, determine whether it is operating properly. This open flare must be equipped with an operational auto-igniter according to the following schedule: • All combustion devices installed on or after May 1, 2014, must be equipped with an operational auto-igniter upon installation of the combustion device; • All combustion devices 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. OPERATING & MAINTENANCE REQUIREMENTS 15. Upon startup of this point, 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 the O&M plan are subject to Division approval prior to implementation. (Regulation Number 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 16. The owner or operator shall demonstrate compliance with opacity standards, using EPA Reference Method 22, 40 C.F.R. Part 60, Appendix A, 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 minute in any fifteen minute period during normal operation. (Regulation Number 7, Sections XVII.B.2. and XVII.A.16) ADDITIONAL REQUIREMENTS 17. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually whenever a significant increase in emissions occurs as follows: For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or AIRS ID: 123/9E56 Page 4 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division e. No later than 30 days before the existing APEN expires. 18. Federal regulatory program requirements (i.e. PSD, NANSR) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Parts C and D). GENERAL TERMS AND CONDITIONS 19. 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. 20. 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. 21. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant 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 applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. 22. 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. 23. 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 applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 24. 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. AIRS ID: 123/9E56 Page 5 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division 25. 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: Andy Gruel, P.E. Permit Engineer Air Pollution Control Division Permit History Issuance Date Description Issuance 1 This Issuance Issued to Carrizo Oil & Gas, Inc. Newly permitted synthetic minor facility. AIRS ID: 123/9E56 Page 6 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder: 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: https://www.colorado.gov/pacific/cdphe/aqcc-reqs 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Controlled Emission Are the Emission AIRS Rate emissions Rate Point Pollutant CAS# (Ib/yr) reportable? (lb/yr) Benzene 71432 6596 Yes 330 Toluene 108883 4859 Yes 243 Ethylbenzene 100414 447 Yes 22 004 Xylenes 1330207 1250 Yes 63 n-Hexane 110543 45511 Yes 2276 2,2,4-Trimethylpentane 540841 672 Yes 34 AIRS ID: 123/9E56 Page 7 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division 5) The emission levels contained in this permit are based on the following emission factors: Point 004: Natural Gas Emission Emission Composition Factors Factors CAS # Pollutant (Weight%) Uncontrolled Controlled Source lb/MMscf lb/MMscf natural gas natural gas vented vented NOx -- 101.09 AP-42, Table 13.5-1, 1486.6 Btu/scf CO --- - 550.04 AP-42, Table 13.5-2 1486.6 Btu/scf VOC 41.255 29,183.6 1,459 Mass Balance 71432 Benzene 0.1386 98.011 4.9005 Mass Balance 108883 Toluene 0.1021 72.201 3.6100 Mass Balance 100414 Ethylbenzene 0.0094 6.638 0.3319 Mass Balance 1330207 Xylenes 0.0263 18.575 0.9287 Mass Balance 110543 n-Hexane 0.9560 676.24 33.8118 Mass Balance 540841 2,2,4-TMP 0.0141 9.980 0.4990 Mass Balance The uncontrolled VOC and HAP emissions for this point were calculated by applying a mass balance on the weighted average of analyses of site-specific gas samples collected 12/4/2015 from the five separators at the facility, and the following assumptions: • Gas flowrate to flare: 1468.2 Mscf/d (based on first 30 days of production) • Limit 1100 hours per year of gas to flare, total from all separators • Pilot gas: 50 scf/hr, for 8760 hr/yr • Permit limit 67.7 MMscf/yr calculated by: [1468.2 Mscf/d * (1 MMscf/ 1000 Mscf) * 365 d/yr* 1100 hr/yr * (1 yr / 8760 hr) ] + [(50 scf/hr * (1 MMscf / 106 scf) * 8760 hr/yr)] = 67.7305 MMscf/yr. This is rounded down to 67.7 per the revised permit application. The controlled VOC and HAP emissions factors for point 004 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 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, HAPs (total, and n-hexane) NANSR Synthetic Minor source of: VOC MACT HH Area Source Requirements: Not Applicable AIRS ID: 123/9E56 Page 8 of 9 Colorado Department of Public Health and Environment Air Pollution Control Division 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 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.qov/pacific/cdphe/air-permit-self-certification AIRS ID: 123/9E56 Page 9 of 9 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Carrizo Oil &Gas, Inc. 16WE0227 (Point 001) Permit Number: 16WE0228.XP (Point 002) 16WE0229 (Point 003) 16WE0230 (Point 004) Source Location: SWNW Section 20 T9N R58W(attainment) Point 001: Nineteen (19)400-BBL aboveground atmospheric crude oil storage vessels. Emissions are controlled by enclosed flare. Point 002: Five(5)400-BBL aboveground atmospheric produced water storage vessels. Emissions are controlled by enclosed flare. Equipment Description: Point 003: Loadout of crude oil to tank trucks. Emissions are not controlled. Point 004: Separator venting and flaring when sales gas pipeline is not available. Open flare. AIRS ID: 123-9E56 Date: 04/11/2016 Review Engineer: Andy Gruel Control Engineer: Stefanie Rucker Section 2—Action Completed Grandfathered Modification Point APEN Required/Permit Exempt 02 x CP1 Transfer of Ownership APEN Exempt/Permit Exempt Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? Yes X No Did the applicant provide ample information to determine emission rates? X Yes No If you answered"no"to any of the above, when did you mail an 4/11/16 Information Request letter to the source? Initial application rec'd 1/15/2016. On 4/11/2016 I requested Alternative Emissions Control (AEC) Device Request Form for On what date was this application complete? open flare at point 004. On 4/11/16 I received revised calcs for Point 004. On 4/13/16 I received revised caics for Point 001,and the AEC form. Page 1 mis Section 4—Source Description AIRS Point Equipment Description Crude oil Nineteen (19)400-bbl fixed roof atmospheric crude oil storage vessels,with total tank(001) capacity 7,600-bbl. Emissions are controlled by enclosed flare. Produced Five (5)400-BBL aboveground atmospheric produced water storage vessels. Water tank Emissions are controlled by enclosed flare. (002) Truck loadout Loadout of crude oil to tank trucks. Emissions are not controlled. (003) Flare/ Separator venting and flaring when sales gas pipeline is not available. This is an Separator open flare(Leed,sn: 80367)with a minimum control efficiency of 95%. (004) Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria Yes X No pollutant? If"yes", for what pollutant? PM,o CO Ozone Is this location in an attainment maintenance area for Yes No any criteria pollutant? If"yes", for what pollutant? (Note: These pollutants are subject to minor source PM10 CO Ozone RACT per Regulation 3, Part B, Section III.D.2) Is this source located in the 8-hour ozone non- attainment region?(Note: If"yes"the provisions of Yes X No Regulation 7, Sections XII and XVII.C may apply) Point 002 (Produced water): Is this source claiming exempt status for this source based on the fraction of oil in the stored water(less than 1% by volume crude X Yes No oil on an average annual basis)? If yes, PERMIT exempt per Regulation 3, Part B, Section II.D.1.m) Point 003 (Loadout): Is this source located at an oil X Yes No and gas exploration site? Point 003(Loadout): If yes, does this source load less than 10,000 gallons of crude oil per day on an annual average, splash fill less than 6750 bbl of condensate Yes X No (hydrocarbons that have an API gravity of 40 degrees or greater) per year or submerged fill less than 16,308 bbl of condensate per year? Point 003 (Loadout): Is this source located at a facility that is considered a major source of hazardous air Yes X No pollutant (HAP) emissions? Point 003(Loadout): Will this equipment be operated in any NAAQS nonattainment area? If yes, source Yes X No might be subject to Reg. 3, Part B, Section 111.O.2. Point 004 (Loadout): Does this source load gasoline Yes X No into transport vehicles? Section 5—Emission Estimate Information AIRS Point Emission Factor Source Crude oil tank Site-specific using E&P Tanks (Refer to Section 14 for calculations) (001) Produced Weld County default emission factors for produced water (PS Memo 09-02) water(002) AP-42: Chapter 5.2, Equation 1 Truck loadout L= 12.46*S*P*M/T (003) L= loading losses in lb per 1000 gallons loaded Page 2 S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T=temperature of bulk liquid loaded [deg. R] Separator/Flare Mass balance using sales gas analysis and Displacement Equation (see Section (004) 14 for calculations) Did the applicant provide actual process data for the emission inventory? X Yes No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production Crude oil tank 296,601 bbl/yr (001) Produced water tank 125,245 bbl/yr (002) Truck loadout 296,601 bbl/yr (003) Separator/Flare 67.7 MMscf/yr (004) Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year Crude oil tank No actual throughput data provided N/A (001) Produced water tank 125,245 bbl/yr 2015 (002) Truck loadout No actual emissions data provided N/A (003) Separator/Flare No actual emissions data provided N/A (004) Basis for Permitted Emissions (Permit Limits) AIRS Point Process Consumption/Throughput/Production Crude oil 296'601 bbl/yr storage (001) Produced water tank N/A— Permit Exempt (002) Truck loadout 296,601 bbl/yr (003) Separator/Flare 67.7 MMscf/yr (004) Does this facility use control devices? X Yes No AIRS Point Process Control Device Description % Reduction Granted Crude oil 01 Leed enclosed flare 95 storage (001) Produced 01 Leed enclosed flare 95 water(002) Separator/Flare 01 Leed open flare, sn: 80367 95 (004) Page 3 Joiliw Section 6—Emission Summary(tons per year) Point NO, VOC CO SOx PM10 Single Total HAP HAP 001 --- 179.91 --- ___ --- 10.86(n- 15.43 hexane) 002 --- 16.41 --- _-_ ___ 1.378 (n- 1.82 PTE: hexane) 003 --- 14.95 --- ___ ___ 0.902 (n- 1.18 hexane) 004 3.40 982.03 18.51 --- --- 22.76 (n- 29.67 hexane) 001 --- 179.91 --- ___ -__ 10.86(n- 15.43 hexane) Uncontrolled point 002 --- 16.41 --- ___ ___ 1.378 (n- 1.816 hexane) source emission rate: 003 --- 14.95 --- ___ -__ 0.902 (n- 1.177 hexane) 004 3.40 982.03 18.51 --- --- 22.76(n- 29.67 hexane) I TOTAL(TPY) 3.40 1193.3 18.51 --- ___ 35.9 (n- 48.09 hexane) 001 0.37 9.00 2.02 _-_ ___ 0.543 (n- 0 772 hexane) 0.069(n- I Controlled point 002 --- 0.82 --- --- --- hexane) 0.091 source emission rate: 003 -- 14.95 --- __ ___ 0.902 (n- 1.177 hexane) 004 3.40 49.1 18.51 --- ___ 1.138(n- 1.484 hexane) TOTALIFICANTS 9.6 2.6 7.3 --- --- 0.8 (TPY) TOTAL INSIGNPERMITTED 3.77 73.05 20.53 --- --- 2.58 3.38 (TPY) Section 7—Non-Criteria/Hazardous Air Pollutants Uncontrolled Are the Controlled Emission Pollutant CAS# Emission Rate emissions r Rate Ib/ (lb/yr) reportable? y ) Crude Oil Storage -Point 001 Benzene 71432 3500 Yes 175 Toluene 108883 3107 Yes 156 Ethylbenzene 100414 360 Yes 18 Xylenes 1130207 838 Yes 42 n-Hexane 110543 21725 Yes 1086 2,2,4-Trimethylpentane 540841 1336 Yes 67 Produced water storage-Point 002 Benzene 71432 877 Yes 44 n-Hexane 110543 2755 Yes 138 L Truck loadout- Point 003 Benzene 71432 291 Yes N/A- Uncontrolled Toluene 108883 259 Yes N/A—Uncontrolled Page 4 n-Hexane 110543 1804 Yes N/A- Uncontrolled Separator/ Flare-Point 004 Benzene 71432 6596 Yes 330 Toluene 108883 4859 Yes 243 Ethylbenzene 100414 447 Yes 22 Xylenes 1130207 1250 Yes 63 n-Hexane 110543 45511 Yes 2276 2,2,4-Trimethylpentane 540841 672 Yes 34 Note: Regulation 3, Part A, Section II.B.3.b APEN emission reporting requirements for non-criteria air pollutants are based on potential emissions without credit for reductions achieved by control devices used by the operator. Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? If"yes", complete the information listed below AIRS Point Process Pollutant Regulatory Basis Test Method Section 9—Source Classification What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V X PSD NA NSR X MACT Is this a modification to an existing permit? Yes X No Section 10—Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes",for which pollutants?Why? VOC For Reg. 3, Part B, III.C.1.a (emissions increase>25/50 tpy)? X Yes No For Reg. 3, Part B, III.C.1.c.iii (subject to MACT)? Yes X No For Reg. 3, Part B, III.C.1.d (synthetic minor emission limits)? X Yes No Section 11 —Modeling Is modeling required to demonstrate compliance with National Ambient Yes X No Air Quality Standards (NAAQS)? If"yes", for which pollutants?Why? AIRS Point Section 12—Regulatory Review Regulation 1 -Particulate, Smoke1Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 All 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. Page 5 Alb 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 004 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 All 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 3-APENs, Construction Permits,Operating Permits, PSD Part A-APEN Requirements Criteria Pollutants: For criteria pollutants, Air Pollutant Emission Notices are required for: each individual emission point in a non-attainment area with All uncontrolled actual emissions of one ton per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is non-attainment. Applicant is required to file an APEN since emissions exceed 1 ton per year VOC. Part B—Construction Permit Exemptions Applicant is required to obtain a permit since uncontrolled VOC emissions 001, 003, 004 from this facility are greater than the 2.0 TPY threshold (Reg. 3, Part B, Section II.D.3.a) Point 002: Applicant is not required to obtain a permit since the stored produced 002 (Produced water contains less than one percent by volume crude oil on an annual average Water) (Reg. 3, Part B, Section II.D.1.m) NSPS OOOO is not applicable because the uncontrolled VOC is less than 6 tpy per vessel. Part B, III.D.2 - RACT requirements for new or modified minor sources 003 (Loadout) This section of Regulation 3 requires RACT for new or modified minor sources located in nonattainment or attainment/maintenance areas. This source is located in the attainment area, so RACT is not required. Regulation 6-New Source Performance Standards NSPS Kb: Tanks are not subject to Kb because each individual vessel is less than 001, 002 75 m3, and the facility is located prior to custody transfer. NSPS OOOO: Crude oil storage vessels are not subject to OOOO because the 001 control requirements under Reg 7 Section XVII bring the controlled emissions below 6 tpy VOC. NSPS OOOO: Total uncontrolled VOC for the produced water tanks is over 6 tpy (16.41 tpy). However, there are five vessels, and NSPS OOOO does not consider 002 liquid-manifolded vessels to be a single"tank". Therefore, the OOOO applicability is based on 16.41 divided by 5, which is less than 6 tpy—and thus, OOOO does not apply for produced water storage at this facility. Page 6 Regulation 7—Volatile Organic Compounds XII. VOLATILE ORGANIC COMPOUND EMISSIONS FROM OIL AND GAS OPERATIONS Section XII does not apply because the material stored is crude oil. 001 (Crude oil storage) XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS... Crude oil storage vessels are located at an E&P site, have a fixed roof, does not contain only stabilized liquids, and have uncontrolled actual emissions greater than 6 tpy VOC. Therefore, this point is subject to Section XVII B, C.1, C.2, C.3. XVII STATEWIDE CONTROLS FOR OIL AND GAS OPERATIONS.... 002(prod water Produced water storage vessels are categorically exempt due to less than 1% by storage) volume crude oil (Reg. 3, Part B, Section II.D.1.m), so Reg 7 Section XVII doesn't apply. 004 XVII The separators were newly constructed after August 1, 2014. Therefore, they (Separator/Flare) are subject to Reg 7 Section XVII.G, and control requirements of Reg 7, XVII.B.2. Regulation 8—Hazardous Air Pollutants 001,002,004 None 003 (Truck MACT EEEE: Not subject because located at a production field facility and thus exempt per 40CFR loadout) 63.2334(c)(1). Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 28.884 VOC No E&P Tanks 95 lb/1000 gal 0.0595 NOx No AP-42 Table N/A lb/1000 gal 13.5-1 0.3240 CO No AP-42 Table N/A lb/1000 gal 13.5-1 0.2810 Benzene No E&P Tanks 95 lb/1000 gal 01 Crude oil Storage Tanks 0.2489 Toluene No E&P Tanks 95 001 lb/1000 gal 0.0289 Ethylbenzene No E&P Tanks 95 lb/1000 gal 0.06743 Xylenes No E&P Tanks 95 lb/1000 gal 1.7436 n-hexane No E&P Tanks 95 lb/1000 gal 0.1076 2.2,4- No E&P Tanks 95 lb/1000 gal Trimethylpentane SCC 40400312—Fixed Roof Tank, Crude Oil,working+breathing+flashing losses 6.2381 VOC No CDPHE PS 95 lb/1000 gal Memo 09-02 0.16667 01 Produced water storage CDPHE PS Benzene No 95 002 lb/1000 gal Memo 09-02 0.52381 n-Hexane No CDPHE PS 95 lb/1000 gal Memo 09-02 SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses 2.40 VOC No AP-42 0 lb/1000 gal 0.0233 Benzene No Eng. Calc. 0 01 Truck Crude oil Loadout lb/1000 gal 003 0.0208 Toluene No Eng. Calc. 0 lb/1000 gal 0.1448 n-hexane No Eng. Calc. 0 lb/1000 gal SCC 40600132: Crude Oil: Submerged Loading (Normal Service) Page 7 29183.6 lb/MMscf VOC No Mass balance 95 vented 101.09 lb/MMscf NOx No AP-42 Ch 13-5 N/A vented 550.04 lb/MMscf CO No AP-42 Ch 13-5 N/A vented 98.011 lb/MMscf Benzene No Mass balance 95 vented 72.201 01 Separator venting and lb/MMscf Toluene No Mass balance 95 004 flaring vented 6.638 lb/MMscf Ethylbenzene No Mass balance 95 vented 18.575 lb/MMscf Xylenes No Mass balance 95 vented 676.24 lb/MMscf n-Hexane No Mass balance 95 vented 9.9801 2,2,4- lb/MMscf Trimethylpen No Mass balance 95 vented tane SCC 31000205— Flares (at a gas production facility) Page 8 Section 14—Miscellaneous Application Notes AIRS Point 001 Crude Oil Storage Tanks The applicant developed site-specific emission factors for VOC and HAPs using E&P Tanks (flashing+working+breathing losses). A site-specific sample was obtained from each of the five wells contributing liquids to the tank battery, and a separate E&P Tanks run was completed using the analytical data and a well production rate based on observed production. The results from the five E&P Tanks runs were combined using a weighted average based on well throughput to arrive at a blended VOC and HAP emission factor for the storage tanks. My calculated results were close to but generally slightly less than those presented in the (revised) application, so I will conservatively accept the values presented in the revised application. VOC: 179.91 tpy*2000/296601 bbl/yr= 1.213 lb/bbl = 28.884 Ib/1000gal Benzene: 1.75 tpy*2000/296601 bbl/yr=0.0118 lb/bbl =0.2810 lb/1000gal Toluene: 1.55 tpy*2000/296601 bbl/yr= 0.0105 lb/bbl =0.2489 lb/1000gal Ethylbenzene: 0.18 tpy*2000/296601 bbl/yr=0.001214 lb/bbl =0.02890 lb/1000gal Xylenes: 0.42 tpy*2000/296601 bbl/yr= 0.00283 lb/bbl =0.06743 lb/1000gal n-Hexane: 10.86 tpy*2000/296601 bbl/yr=0.07323 lb/bbl = 1.7436 lb/1000gal 2,2,4-TMP: 0.67 tpy*2000/296601 bbl/yr= 0.00452 lb/bbl =0.1076 Ib/1000gal NOx and CO emissions were calculated using the AP-42 emission factors of 0.068 lb NOx/MMBtu and 0.37 lb CO/MMBtu. The application presented a conservatively estimated potential tank vapor volume to flare of 8.4 Mscf/d, and a pilot gas rate of 4.0 Mscf/d. This is extrapolated to 4.5 MMscf/yr. The estimated heating value of the gases is 2870 Btu/scf(tank vapors) and 1486.6 Btu/scf(pilot gas). Applying a weighted average based on the tank vapor and pilot gas volumes, the assumed average heating value of the gas combusted at the flare is (2870 *8.4/12.4) + (1486.6*4.0/12.4) = 2423.7 Btu/scf. This heating value is multiplied by the total volume to obtain the MMBtu throughput. NOx: 4.5 MMscf/yr*2423.7 MMBtu/MMscf*0.068 lb NOx/MMBtu =742 lb NOx/yr= 0.37 tpy CO: 4.5 MMscf/yr*2423.7 MMBtu/MMscf*0.37 lb CO/MMBtu =4036 lb CO/yr=2.02 tpy These emissions quantities are converted to a lb/1000gal basis as follows: NOx: 742 lb/yr/296601 bbl/yr= 0.0025 lb/bbl = 0.0595 lb/1000gal CO: 4036 lb/yr/296601 bbl/yr= 0.0136 lb/bbl = 0.3240 lb/1000gal AIRS Point 002 Produced water storage(permit-exempt) The applicant used the Weld County default emission factors per PS Memo 09-02. VOC: 0.262 lb/bbl * 125,245 bbl/yr= 32814.2 lb/yr= 16.41 tpy Benzene: 0.007 lb/bbl * 125,245 bbl/yr= 876.7 lb/yr= 0.44 tpy n-Hexane: 0.022 lb/bbl * 125,245 bbl/yr=2755.4 lb/yr= 1.38 tpy Page 9 AIRS Point 003 Truck crude oil Loadout AP 42: Chapter 5.2 Equation 1 L= 12.46*S*P*M/T L= loading losses in lb per 1000 gallons loaded S = Saturation Factor P = true vapor pressure of liquid loaded [psia] M = molecular weight of vapors [lb/lb-mole] T= temperature of bulk liquid loaded [deg. R] 1 degree Fahrenheit = 460.67 degree Rankine Criteria Pollutants Variables S 0.6 Submerged loading: dedicated normal seance P 3.4 psia M 50 lb/lb-mole T 529.67 deg. R L 2.40 lb/10^3 gal 0.100777 lb/bbl Annual requested Throughput 12,457,242 Gallons per Year Annual requested VOC emissions 2•,;• Pounds per Year 1-.•5 Tons VOC .erYear Non-Criteria Reportable Air Pollutants/Hazardous Air Pollutants Weighted Avg VOC E.F. Tank E.F. from from E&P Are E&P Tanks Tanks Ratio HAP to Emissions Emissions Emission Corn•onent (lb/BBL (lb/bbl VOC E.F. lb/ r Reportable? Factor lb/bbl Benzene 1.18E-02 1.213 0.0097 291 Yes 0.000980 Toluene 1.05E-02 1.213 0.0087 259 Yes 0.000872 n-hexane 7.32E-02 1.213 0.0603 1,804 Yes 0.006082 NCRP emissions were estimated as follows: E&P Tanks modeling was performed on five site-specific samples from the wells on-site. The resulting emission factors for each NCRP and for VOC were used to derive the loadout emission factor. The HAP emission factor divided by VOC emission factor multiplied by the total VOC loadout emissions calculated above equals the total HAP emissions. Emission factors for HAPS are: Benzene = (291 lb/yr)/(296,601 bbl/yr) = 0.000980 lb/bbl = 0.0233 lb/1000gal Toluene= (259 Ib/yr)/(296,601 bbl/yr) = 0.000872 lb/bbl = 0.0208 lb/1000gal n-hexane= (1804 Ib/yr)/(296,601 bbl/yr) = 0.006082 lb/bbl =0.1448 lb/1000gal Page 10 AIRS Point 004 Separator venting and flaring when sales pipeline is down The applicant used a mass balance approach to calculated emissions from separator venting/flaring when the sales pipeline is down. The applicant provided site-specific analyses from each of the five wells which were then converted into mass fraction terms. Below are the results for each of the five wells: Sample date 12/4/2015 --- ... ....._ Sample date Well 13-20 ___. . __._.12/42015 ._. _..... mole% MW Ibx/lbmol mass fraction Wel 14-20 Helium 0.12 40026 0.005 0.014 mole% MW Ibx/lbmol mass fraction CO2 2.44 44.01 1.074 3.145 Helium 0.01 4.0026 0.000 0.002 N2 0.57 28.013 0.160 0.468 CO2 2.48 44.01 1.091 4.457 • N2 0.99 28.013 0.277 _ 1.133 methane 42.6003 16.041 6.834 20.015 ethane 16.5598 30.063 4.978 14582 methane 68.6821 16.041 11.017 44.994 ethane 11.7899 30.063 3.544 14.475 propane 19.067 44.092 8.4070 24.624 isobutane 2.203 58.118 1.2803 3.750 propane 9.304 44.092 4.1022 16.753 isobutane 0.932 58.118 0.5414 2.211 n-butane 8.1899 58.118 4.7598 13.941 isopentane 1.8209 72.114 1.3131 3.846 n-butane 3.2781 58.118 1.9052 7.781 n-pentane 2.6015 72.114 1.8760 5.495 isopentane 0.6329 72.114 0.4564 1.864 n-pentane 0.8478 72.114 0.6114 2.497 cyclopentane 0.2577 70.13 0.1807 0.529 n-Hexane 0.7412 86.18 0.6388 1.871 cyclopentane 0.0742 70.13 0.0520 0.213 n-Hexane 0.1945 86.18 0.1676 0.685 cyclohexane 0.2003 84.16 0.1686 0.494 _.. Other hexanes 1.2743 86.18 1.0982 3.217 cyclohexane 0.0510 84.16 0.0429 0.175 Other hexanes 0.3426 86.18 0.2953 1.206 heptanes 0.6753 100.21 0.6767 1.982 methylcyclohexane 0.1514 98.19 0.1487 0.435 heptanes 0.1756 100.21 0.1760 0.719 224-TMP 0.0098 11423 0.0112 0.033 methylcyclohexane 0.0414 98.19 0.0407 0.166 224-TMP 0.0023 114.23 0.0026 0.011 Benzene 0.1184 78.12 0.0925 0.271 Toluene 0.0724 92.15 0.0667 0.195 Benzene 0.0320 78.12 0.0250 0.102 Ethylbenzene 0.0049 106.17 0.0052 0.015 Toluene 0.0202 92.15 0.0186 0.076 Xylenes 0.0143 106.17 0.0152 0.044 Ethylbenzene 0.0016 106.17 0.0017 0.007 C8+Heaues 0.2938 120.d 0.3526 1.033 Xylenes 0.0044 106.17 0.0047 0.019 VOC mass fraction: 61.7761 C8+Heaues 0.0931 120.0 0.1117 0.456 VOC mass fraction: 34.9393 Fuel Heating Value 1862.1 - -- -- - _ Fuel Heating Value 1360.4 Gas Production(Mcfhr)) 139760_.. Gas Production(Mcf/yr)) ... . 126220 Sample date __.. __.... 12/4/2015 .... _. .. Wel 15-20 Sample date 12/4/2015 mole% MW Ibx/lbmol mass fraction • Wel 16-20 Helium 0.01 4.0026 0.000 0.002 mole% MW Ibx/Ibmol mass fraction CO2 2.42 44.01 1.065 4453 N2 1.04 28.013 0.291 1.218 • Helium 0.02 4.0026 0.001 0.003 methane 70.1574 16.041 11.254 47.055 CO2 2.43 44.01 1.069 4.475 ethane 11.4584 30.063 3.445 14.403 N2 1.04 28.013 0.291 1.219 propane 88161 44092 3.8872 16.253 methane 70.0115 16.041 11.231 46.992 isobutane 0.8641 58.118 0.5022 2.100 ethane 11.5827 30.063 3.482 14.570 n-butane 3.0302 58.118 1.7611 7.363 propane 8.9844 44.092 3.9614 16.576 isopentane 0.5688 72.114 0.4102 1.715 isobutane 0.8757 58.118 0.5089 2.130 n-pentane 0.7638 72.114, 0.5508 2.303 n-butane 3.0089 58.118 1.7487 7.317 cyclopentane 0.0583 70.13 0.0409 0.171 isopentane 0.5383 72.114 0.3882 1.624 n-Hexane 0.1628 86.18 0.1403 0.587 n-pentane 0.7054 72.114 0.5087 2.129 cyclohexane 0.0393 84.16 0.0331 0.138 cyclopentane 0.0603 70.13 0.0423 0.177 . Other hexanes 0.2755 86.18 0.2374 0.993 n-Hexane 0.1475 86.18 0.1271 0.532 heptanes 0.1337 100.21 0.1340 0.560 cyclohexane 0.0382 84.16 0.0321 0.135 methylcyclohexane 0.0317 98.19 0.0311 0.130 Other hexanes 0.2644 86.18 0.2279 0.953 224-TMP 0.0001 114.23 0.0001 0.000 heptanes 0.1276 100.21 0.1279 0.535 Benzene 0.0231 78.12 0.0180 0.075 methylcyclohexane 0.0293 98.19 0.0288 0.120 Toluene 0.0145 92.15 0.0134 0.056 224-TMP 0.0018 11423 0.0021 0.009 Ethylbenzene 0.0021 106.17 0.0022 0.009 _ Benzene 0.0245 78.12 0.0191 0.080 Xylenes 0.0049 106.17 0.0052 0.022 Toluene 0.0149 92.15 0.0137 0.057 C8+Heaues 0.0782 120.0 0.0938 0.392 • Ethylbenzene 0.0013 106.17 0.0014 0.006 VOC mass fraction: 32.8687 Xylenes 0.0032 106.17 0.0034 0.014 Fuel Healing Value 13317 C8+Heaues 0.069 120.01 0.0828 0.346 VOC mass fraction: 32.7402 Gas Production(Mcf/yr)) ...__. 83610 _.. _.. _. Fuel Heating Value 1329.9 Gas Reduction(Mcf/yr)) 102672 (continued) Page 11 (Point 004 continued) Sanple date 12/4/2015 Wel 17-20 _. mole% MW Ibx/Ibmol mass fraction Helium 0.01 4.0026 0.000 0.002 CO2 2.46 44.01 1.083 4.411 N2 1.01 28.013 0.283 1.153 methane 68.7769 16.041 11.033 44.946 ethane 11.5578 30.063 3.475 14.155 propane 9.2143 44.092 4.0628 16.552 isobutane 0.9344 58.118 0.5431 2.212 n-butane 3.3409 58.118 1.9417 7.910 isopentane 0.6522 72.114 0.4703 1.916 n-pentane 0.8886 72.114 0.6408 2.611 cyclopentane 0.0799 70.13 0.0560 0.228 n-Hexane 0.2069 86.18 0.1783 0.726 cyclohexane 0.0553 84.16 0.0465 0.190 Other hexanes 0.364 86.18 0.3137 1.278 heptanes 0.1907 100.21 0.1911 0.779 methylcyclohexane 0.0438 96.19 0.0430 0.175 224-71 AP 0.0018 114.23 0.0021 0.008 Benzene 0.0337 78.12 0.0263 0.107 Toluene 0.023 92.15 00212 0.086 Ethylbenzene 0.0018 106.17 0.0019 0.008 Xylenes 0.006 106.17 0.0064 0.026 C8+Heaves 0.1066 120.0 0.1279 0.521 VOC mass fraction: 35.3337 Fuel Heating Value 13632 Gas Production(Mcf/yr)) 83640 The mass fraction data from the five wells was used to obtain a weighted average mass fraction based on the projected gas throughput: Sample date 12/4/2015 12/4/2015 12/4/2015 12/4/2015 12/4/2015 VUE]GHTED AVERAGE Well 13-20 14-20 15-20 16-20 17-20 mass frac% mass frac%mass frac% mass frac% mass frac% mass frac Helium 0.0141 0.0016 0.0017 0.0033 0.0016 0.0052 CO2 3.1453 4.4574 4.4532 4.4749 4.4106 • 4.1106 N2 0.4677 1.1326 1.2181 1.2190 1.1526 • 0.9922 methane 20.0153 44.9940 47.0551 46.9922 44.9459 • 39.1766 ethane 14.5816 14.4751 14.4032 14.5703 14.1554 • 14.4600 propane 24.6240 16.7531 16.2532 16.5758 16.5515 • 18.6624 isobutane 3.7501 2.2109 2.0998 2.1296 2.2124 • 2.5796 n-butane 13.9414 7.7806 7.3635 7.3172 7.9102 l' 9.2537 isopentane 3.8461 1.8639 1.7151 1.6243 1.9161 • 2.3199 n-pentane 5.4949 2.4968 2.3030 2.1285 2.6106 ' 3.1957 cyclopentane 0.5293 0.2125 0.1710 0.1769 0.2283 • 0.2843 n-Hexane 1.8709 0.6846 0.5866 0.5319 0.7264 ' 0.9560 cyclohexane 0.4937 0.1753 0.1383 0.1345 0.1896 P 0.2470 Other hexanes 3.2166 1.2058 0.9927 0.9534 1.2780 ' 1.6599 - heptanes 1.9821 0.7186 0.5602 0.5350 0.7785 ' 0.9976 methylcyclohexane 0.4354 0.1660 0.1301 0.1204 0.1752 • 0.2234 224-TMP 0.0328 0.0107 0.0005 0.0086 0.0084 • 0.0141 Benzene 0.2709 0.1021 0.0755 0.0801 0.1073 • 0.1386 Toluene 0.1954 0.0760 0.0559 0.0575 0.0863 • 0.1021 Ethylbenzene 0.0152 0.0069 0.0093 0.0058 0.0078 • 0.0094 Xylenes 0.0445 0.0191 0.0218 0.0142 0.0260 • 0.0263 C8+ Heavies 1.0326 0.4563 0.3924 0.3465 0.5211 0.5857 Fuel Heating Value 1882.1 1360.4 1331.7 1329.9 1363.2 ' 1486.6 Gas Production(Mcf/yr)) 139760 126220 83610 102672 83640 ' 535902 Proportion of Throughput 26.08% 23.55% 15.60% 19.16% 15.61% (continued)- Page 12 (Point 004 continued): Using the weighted average calculated above, I used the Displacement Equation to apply a mass balance for emissions estimation: Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=O*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/Ib-mol)at 60F and 1 atm 5.72 MMscf/mo Throughput (Q) 67.3 MMscf/yr 7682.6 scf/hr MW 26.81 lb/lb-mol 0.00162 MMscf/d mass fraction % mass fraction E lb/hr lb/yr tpy Helium 0.0052 0.00005 Helium 0.0 248 0.12 CO2 4.1106 0.04111 CO2 22.3 195694 97.85 N2 0.9922 0.00992 N2 5.4 47237 23.62 methane 39.1766 0.39177 methane 212.9 1865088 932.54 ethane 14.4600 0.14460 ethane 78.6 688400 344.20 propane 18.6624 0.18662 propane 101.4 888463 444.23 isobutane 2.5796 0.02580 isobutane 14.0 122809 61.40 n-butane 9.2537 0.09254 n-butane 50.3 440541 220.27 isopentane 2.3199 0.02320 isopentane 12.6 110443 55.22 n-pentane 3.1957 0.03196 n-pentane 17.4 152137 76.07 cyclopentane 0.2843 0.00284 cyclopentane 1.5 13535 6.77 n-Hexane 0.9560 0.00956 n-Hexane 5.2 45511 22.76 cyclohexane 0.2470 0.00247 cyclohexane 1.3 11759 5.88 Other hexanes 1.6599 0.01660 Other hexanes 9.0 79022 39.51 heptanes 0.9976 0.00998 heptanes 5.4 47493 23.75 methylcyclohexai 0.2234 0.00223 methylcyclohexane 1.2 10634 5.32 224-IMP 0.0141 0.00014 224-IMP 0.1 672 0.34 Benzene 0.1386 0.00139 Benzene 0.8 6596 3.30 Toluene 0.1021 0.00102 Toluene 0.6 4859 2.43 Ethylbenzene 0.0094 0.00009 Ethylbenzene 0.1 447 0.22 Xylenes 0.0263 0.00026 Xylenes 0.1 1250 0.63 C8+ Heavies 0.5857 0.00586 C8+ Heavies 3.2 27883 13.94 Total VOC Emissions (Uncontrolled) 982.0268 annual limit assuming 95% control 49.10 Notes ........ __.. __ ___. Throughput(O)is taken from the reused calculation sheets and calculated as follows: 1468.2 Mscf/d gas'.ented(based on first 30 days production)'365 d'(1100 hrs/8760 hrs)=67.2925 MMscf/yr. Pilot gas at 50 scf/hr*8760 hr=0.438 MMscf/yr. _.. Total throughput: 67.2925+0.438=67.7305 MMscf/yr. This amount is rounded down to 67.7 MMscf/yr for the permit limit. Total hours of'.enting limited to 1100 hours per year. Mole%,MW,and mass fractions from weighted average of site-specific gas analyses sampled 12/4/2015. The au:rage MW of C8+is assumed using the gas analysis data. (continued) Page 13 (point 004 continued): Flaring Information Equipment Description Flare to combust produced gas during sales gas pipeline downtime. Manufacturer Leed Model 25' Serial Number 80367 Gas Heating Value 1486.6 Btu/scf Throughput 100048.18 MMBtu/yr Combustion emission factor source: AP-42: Chapter 13.5 0.068 lb NOX/MMBtu 0.37 lb CO/MMBtu 3.40 tpy NOX 18.51 tpy CO Emission Factors Uncontrolled NOX 101.09 lb/MMscf natural gas vented CO 550.04 lb/MMscf natural gas vented VOC 29183.6 lb/MMscf natural gas vented Benzene 98.011 lb/MMscf natural gas vented Toluene 72.201 lb/MMscf natural gas vented Ethylbenzene 6.638 lb/MMscf natural gas vented Xylenes 18.575 lb/MMscf natural gas vented n-Hexane 676.24 lb/MMscf natural gas vented 224-TMP 9.9801 lb/MMscf natural gas vented Controlled NOX 101.09 lb/MMscf natural gas vented CO 550.04 lb/MMscf natura gas vented VOC 1459 lb/MMscf natura gas vented Benzene 4.9005 b/MMscf natura gas vented Toluene 3.6100 b/MMscf natura gas vented Ethylbenzene 0.3319 b/MMscf natura gas vented Xylenes 0.9287 b/MMscf natura gas vented n-Hexane 33.8118 b/MMscf natura gas vented 224-TMP 0.4990 b/MMscf natura gas vented Page 14 o •ov r .. 3 3 3 3 3 •° E Z14\ ce ° c 0 o 0 0 o e o W o so u-1 O C7 W 3 3 3 3 3 a Z - U a, " .r u d l'7 M M eN AN ON R m �` O N C C C �C �C O LU ai ` �/ ON ON ON O N 3 0 0 0 0 0 h Y, ;� ,. = C� Q (� L Q b b o a °' (� Q+ ❑ C A E _ M- cc .. �/� L .C 'O u O N, L R > `a l u .0 N W 6, c� C . �' y Y C yq o "Z d C� a ? a W a o 0 0 0 0 o °o° °'-'v ,, o. _ ce o e+i. 73 ad :.E F E sa z z z z z .= �„ R °� w poy 211 to (J `e aal a a, " E y y <y <N <� ate, ° o a 00 _ o ° ° c y 0 • �„ ''0 v w 40 v u v v o O U yl •0 L 3 O a p v .-) O //�� R O V L v .C 0 'O r u �. > '• 3 .a , O > O 0 > o 6. .... ti F�1 .u. .. .N L u U [� L °A ❑ ❑ ❑❑❑ E w v Di) L C L .O Q ci G IY��1I GA u G •• O = L. 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