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Home My WebLink About20160595.tiff co E ' COLORADO CO t Department of Public Health&Environment Dedicated to protecting and improving the health and environment of the people of Colorado Weld County - Clerk to the Board 1150O St PO Box 758 RECEIVED Greeley, CO 80632 February 4, 2016 FEB 0 8 2016 WELD COUNTY COMMISSIONERS Dear Sir or Madam: On February 10, 2016, the Air Pollution Control Division will begin a 30-day public notice period for Nighthawk Production LLC - Blackcomb 3-14. 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, 74-2 Cdc, La) Clara Clara Gonzales Public Notice Coordinator Stationary Sources Program Air Pollution Control Division Enclosure C : (D 141_ �II 2016-0595 1' -cP-6' 4300 Cherry Creek Drive S., Denver, CO 80246-1530 P 303-692-2000 www.colorado.gov/cdphe « ;,°- John W. Hickenlooper, Governor I Larry Wolk,MD,MSPH, Executive Director and Chief Medical Officer ; *'. CDPHE Air Pollution Control Division CO If Notice of a Proposed Project or Activity Warranting Public Comment Website Title: Nighthawk Production LLC - Blackcomb 3-14 - Weld County Notice Period Begins: February 10, 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: Nighthawk Production LLC Facility: Blackcomb 3-14 Oil and gas well production Facility NENW SEC 14 T6S R54W Weld County The proposed project or activity is as follows: Applicant proposes to construct new well production facility 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 The Division has made a preliminary determination of approval of the application. A copy of the application, the Division's analysis, and a draft of Construction Permit 15LI1335 have been filed with the Weld County Clerk's office. A copy of the draft permit and the Division's analysis are available on the Division's website at https://www.colorado.gov/pacific/cdphe/air-permit-public-notices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Christopher Kester Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South, APCD-SS-B1 Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us Aviv COLORADO 1 ( = STATE OF COLORADO w0c Co�.. COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION I ' TELEPHONE: (303)692-3150 * *' *1876 CONSTRUCTION PERMIT PERMIT NO: 15L11335 Issuance 1 DATE ISSUED: ISSUED TO: Nighthawk Production LLC THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as Blackcomb 3-14, located in the NENW of Section 14, Township 6S, Range 54W, in Lincoln County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment Point Description ID VENT 003 One heater treater controlled by one enclosed combustor that achieves a minimum control efficiency of 95% THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S.(25-7-101 et seq),TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division)no later than fifteen days after 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-permitting-notices. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days(180)after issuance of this permit,compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. Within one hundred and eighty days (180) after issuance of this permit, the operator shall install a flow meter to monitor and record volumetric flow rate of natural gas vented from the heater treater.The operator shall use the gas flow rate listed in the application for actual flow AIRS ID: 073/0154/003 Page 1 of 8 Dof De en f Public PollutionHealthand Control DivisionEnvironment rate until the flow meter is installed, not to exceed one hundred and eighty(180)days after issuance of this permit. 4. 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 fora 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.) 5. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self-certification process. (Reference:Regulation No. 3, Part B, Section III.E.) 6. The operator shall retain the permit final authorization letter issued by the Division, after completion of self-certification,with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7. Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis). (Reference: Regulation No. 3, Part B, Section II.A.4) Annual Limits: Facility AIRS Tons per Year Equipment ID Point NO. VOC CO Emission Type VENT 003 --- 5.6 --- Point See "Notes to Permit Holder#4"for information on emission factors and methods used to calculate limits. Facility-wide emissions of each individual hazardous air pollutant,shall be less than 8.0 tpy. Facility-wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level)from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility. 8. The emission points in the table below shall be operated and maintained with the control equipment as listed in order to reduce emissions to less than or equal to the limits established in this permit(Reference: Regulation No.3, Part B, Section III.E.) Facility AIRS Pollutants Equipment Point Control Device Controlled ID VENT 003 Enclosed Combustor VOC AIRS ID: 073/0154/003 Page 2 of 8 I ol. • De en f Public Health and Environment Air Pollution Control Division PROCESS LIMITATIONS AND RECORDS 9. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the throughput shall be maintained by the applicant and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Process Parameter Annual Limit Equipment ID Point VENT 003 Natural gas flaring 10.7 MMscf/yr The owner or operator shall calculate monthly process rates based on the calendar month. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months'data. The permit holder shall calculate throughput each month and keep a compliance record on site or at a local field office with site responsibility,for Division review. 10. The owner or operator shall continuously monitor and record the volumetric flow rate of natural gas vented from the heater treater 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 specified in Condition 12 and to calculate emissions as described in this permit. (for high pressure) STATE AND FEDERAL REGULATORY REQUIREMENTS 11. The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (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,t Section I I.A.1. &4.) 13. These sources are subject to the odor requirements of Regulation No. 2. (State only enforceable) 14. 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; 15. The separator covered by this permit is subject to Regulation 7,Section XVII.G. (State Only). On or after August 1, 2014, gas coming off a separator, produced during normal operation from any newly constructed, hydraulically fractured, or recompleted oil and gas well, must either be routed to a gas gathering line or controlled from the date of first production by air AIRS ID: 073/0154/003 Page 3 of 8 D of De en f Public Health and Environment Air Pollution Control Division pollution control equipment that achieves an average hydrocarbon control efficiency of 95%. If a combustion device is used, it must have a design destruction efficiency of at least 98% for hydrocarbons. OPERATING & MAINTENANCE REQUIREMENTS 16. Upon startup of this point,the applicant shall follow the operating and maintenance(O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Initial Testing Requirements 17. 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 18. On an annual basis,the operator shall complete a site specific extended gas analysis of the natural gas vented from this emissions unit in order to verify the VOC content (weight fraction) of this emission stream. Results of testing shall be used to calculate site-specific emission factors for the pollutants referenced above (in units of lb/MMSCF gas vented) using Division approved methods. Emission factors established through this periodic testing shall be less than or equal to,the emissions factors established in the permit application and "Notes to Permit Holder" for this emissions point. If the site specific emissions factor developed through this sampling and analysis is greater than the emissions factor established in the permit application and"Notes to Permit Holder"the operator shall submit to the Division within 60 days, a request for permit modification to update emissions factors and emissions limits specified in this permit.The,owner or operator shall continue to use the emissions factors established in the permit application and "Notes to Permit Holder" to calculate actual emissions and demonstrate compliance with the emissions limits specified in this permit unless a modification is submitted to the Division. Records of site-specific sampling and emissions factor analysis shall be recorded and maintained by the operator and made available to the Division for inspection upon request. ADDITIONAL REQUIREMENTS 19. 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 AIRS ID: 073/0154/003 Page 4 of 8 I ' , , ol. '• De . en f Public Health and Environment Air Pollution Control Division 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. 20. 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 Part D). GENERAL TERMS AND CONDITIONS 21. 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. 22. 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. 23. 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. 24. 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. 25. 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 AIRS ID: 073/0154/003 Page 5 of 8 L D of De en f Public Health and Environment Air Pollution Control Division 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. 26. 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. 27. Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative,civil or criminal enforcement actions under Sections 25-7-115(enforcement), -121 (injunctions), -122(civil penalties), -122.1 (criminal penalties), C.R.S. By: Christopher Kester Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Nighthawk Production, LLC t AIRS ID: 073/0154/003 Page 6 of 8 L oh • De en )f 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 permittee 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 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 permittee 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. Uncontrolled Are the Controlled AIRS Pollutant CAS# Emission Rate emissions Emission Rate Point (lb/yr) reportable? (Ib/yr) Benzene 71432 35 No 2 Toluene 108883 44 No 2 003 Ethylbenzene 100414 27 No 2 Xylenes 1130207 39 No 2 n-Hexane 110543 5544 Yes 277 5) The emission levels contained in this permit are based on the following emission factors: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled NOx 52.5 52.5 AP-42 Chapter 13.5; lb/MMscf lb/MMscf Emission factors CO ___ 262.2 262.2 back-calculated to lb/MMscf lb/MMscf units of lb/MMscf VOC 27.51 20,892 1,044 Engineering lb/MMscf lb/MMscf Calculation 71432 Benzene 0.0043 3.30 0.16 Engineering lb/MMscf lb/MMscf Calculation 108883 Toluene 0.0054 4.13 0.21 Engineering lb/MMscf lb/MMscf Calculation 2.52 0.13 Engineering 100414 Ethylbenzene 0.0033 lb/MMscf lb/MMscf Calculation AIRS ID: 073/0154/003 Page 7 of 8 Dof De en f Public PollutionHealthand Control DivisionEnvironment Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled 1330207 Xylenes 0.0048 3.64 0.18 Engineering lb/MMscf lb/MMscf Calculation 110543 n-hexane 0.6845 520.04 26.00 Engineering lb/MMscf lb/MMscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the April 16, 2015 analysis of a gas sample collected from the Mary Jane 8-5 tank battery facility. The controlled VOC and HAP emissions factors for point 003 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 PSD True Minor 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 7777—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: htto://www.colorado.aov/pacific/cdghe/air-permit-self-certification AIRS ID: 073/0154/003 Page 8 of 8 Colorado Air Permitting Project Project Details Review Engineer: Christopher Kester Package#: 338186 Received Date: 9/28/2015 Review Start Date: 1/11/2015 Section 01-Facility Information Company Name: Nighthawk Production LLC County AIRS ID: 073 Plant AIRS ID: 0154 Facility Name: Blackcomb 3-17 Physical Address/Location: NENW SEC 14 TES R54W Type of Facility: Oil Stabilization{Exploration&'Production) What industry segment? Oil&Natural Gas Production&Processing Is this facility located in a NAAQS non-attainment area? No If yes,for what pollutant? carbon Monoxide(CO) ❑Particulate Matter(PM) ['Ozone(NOx&VOC) Section 02-Emissions Units In Permit Application Emissions Self Cert AIRS Point# Emissions Source Type Permit# Issuance# Action Engineering Remarks Control? Required? 001 Crude Oil Storage Tank No 15LI1333.XA 1 No APEN Exempt,;: 002 Produced Water Storage Tank No 15LI1334.XA 1 No APEN Exempt Permit Initial 003 Separator Venting Yes 15L11335 1 Yes Issuance Permit Initial 004 Natural Gas RICE Yes 15LI1336 1 Yes Issuance Section 03-Description of Project Reporting and permitting of new sources at a synthetic minor facility. Section 04-Public Comment Requirments Is Public Comment Required? Yes If yes,why?" Requesting Synthetic Minor Permit Section 05-Ambient Air Impact Analysis Requirements Was a quantitative modeling analysis required?2 No If yes,for what pollutants? Colorado Air Permitting Project If yes,attach a copy of Technical Services Unit modeling results summary. Section 06-Facility-Wide Stationary Source Classification Is this stationary source a true minor? Is this stationary source a synthetic minor? If yes,explain what programs and which pollutants here: Prevention of significant Deterioration(PSQ):VOC TitleVOperatingPermits(OP):VOC 1 Is this stationary source a major source? If yes,explain what programs and which pollutants here: • Condensate Storage Tank(s)Emissions Inventory Issuance Date: December 30,2015 Section 01-Adminstrative Information 073 0154 001 Facility Allis ID: .. County Plant Point Section 02-Equipment Description Details Detailed Emissions Unit Five 5.400'bblfxed roof crude on() storage tanks.Emissions from the tanks are not controlled Description: Emission Control Device N/A Description: Requested Overall VOC&HAP Control 0 Efficiency%: Section 03-Processing Rate Information for Emissions Estimates Primary Emissions-Storage Tank(s) Actual Crude Throughput= 45,639 Barrels(bbl)per year Actual Condensate Throughput While Emissions Controls Operating= 0 Requested Permit Limit Throughput= 54,767 Barrels(bbl)per year Potential to Emit(PTE)Crude Throughput= 54,767 Barrels(bbl)per year Secondary Emissions-Combustion Device(s) Heat content of waste gas= N/A Btu/scf Volume of waste gas emitted per BBL of liquids produced= N/A scf/bbl Actual heat content of waste gas routed to combustion device= --- MMBTU per year Request heat content of waste gas routed to combustion device= --- MMBTU per year Potential to Emit(PTE)heat content of waste gas routed to combustion device= --- MMBTU per year Section 04-Emissions Factors&Methodologies i Will this storage tank emit flash emissions? Crude Oil Storage Tanks Control Device Uncontrolled E.F. Uncontrolled Pollutant Uncontrolled E.F. Controlled E.F. (lbs/MMBtu E.F.(lbs/bbl Emissions Factor Source Citation (lbs/bbl Crude Oil (lbs/bbl Crude waste heat Condensate Throughput) Oil Throughput) combusted) Throughput) PM2.5 VilOIN,4O0O01OO 7.. .- \\\\mil\\\\ -_ ® �� 'HI 00008 0.001 X\I \A\\\\\`� �' a'a rlrofi q... o y« 0.000000 0.000 \V�6 \\\ yad a �f 0000000 0.000 \\\\ �\\\\ � 0.000000 0.800 \\\\ 6\\\\• ' /� 0.000000 0.000 " b 0.000110 0.800 \\\\\1\\\V w , 0.000000 0.000 \\\\X-NN- \� :� . .-: Section 05-Emissions Inventory Potential to Emit Requested Permit Limits Actual Emissions Criteria Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) PM10 PM2.5 NOx VOC 0.023 0.023 0.023 0.019 0.019 CO .-. ... ... ... _. Potential to Emit Requested Permit Limits Actual Emissions Hazardous Air Pollutants Uncontrolled Uncontrolled Controlled Uncontrolled Controlled (tons/year) (tons/year) (tons/year) (tons/year) (tons/year) Benzene 0.0000 0.0000 0.0000 0.0000 0.0000 Toluene 0.0000 0.0000 0.0000 0.0000 0.0000 Ethylbenzene 0.0000 0.0000 0.0000 0.0000 0.0000 Xylene 0.0000 0.0000 0.0000 0.0000 0.0000 n-Hexane 0.0030 0.0030 0.0030 0.0025 0.0025 224 TMP 0.0000 0.0000 0.0000 0.0000 0.0000 3 of 11 K:\PA\2015\15LI1335.CP1.xlsm Condensate Storage Tank(s)Emissions Inventory , Issuance Date: December 30,2015 ;action 07-Initial and Parlodk Samoans and Tasting Reauirpngnts Does the company use the state default emissions factors to estimate emissions? IIIIIIIIIIIII ff yes,are the uncontrolled actual or requested emissions estimated to be greater than or equal to 80 tons VOC per year? ff yes,the permit will contain an"Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01. Does the company use a site specific emisions factor to estimate emissions? ff yes and if there are flash emissions,are the emissions factors based on a pressurized liquid sample drawn at the facility being permitted?This sample should be considered representative which generally means site-specific and collected within one year of the application received date.However,if the facility has not been modified(e.g.,no new wells brought on-line),then It may be appropriate to use an older site-specific sample. If no,the permit will contain an'Initial Compliance"testing requirement to develop a site specific emissions factor based on guidelines in PS Memo 05-01- Does the company request a control device efficiency greater than 95%for a flare or combustion device? If yes,the permit will contain and intial compliance test condition to demonstrate the destruction efficiency of the combustion device based on inlet and outlet concentration sampling ;action 08-ledinial NotCl.r.. Source saltactedgraMmitredliftridsuMPleircall the rtnfthetteatertreatutm4 asaksdlsampleonAprifl6y2O15im01Sbe glat•mmb3-1Kwafl.Thesewere ussdashqutstotheE&PTanite sbnolatfontfatwastiierFto-develop dtespe¢Trkemiadantastos; ,..; action 09-Inventory SCC Coding and Emissions Factors Uncontrolled Emissions AIRS Point If Process* SCC Code Pollutant Factor Control% Units 001 01 PM10 — 0 lb/1,000 gallons condensate throughput PM2.5 — 0 lb/1,000 gallons condensate throughput NOx — 0 lb/1,000 gallons condensate throughput VOC 0.020 0 lb/1,000 gallons condensate throughput CO — 0 lb/1,000 gallons condensate throughput Benzene 0.000 0 lb/1,000 gallons condensate throughput Toluene 0.000 0 lb/1,000 gallons condensate throughput Ethylbenzene 0.000 0 lb/1,000 gallons condensate throughput Xylene 0.000 0 lb/1,000 gallons condensate throughput n-Hexane 0.003 0 lb/1,000 gallons condensate throughput 224 TMP 0.000 0 lb/1,000 gallons condensate throughput 4 of 11 K:\PA\2015\15LI1335.CP1adsm 002 Four(4)above ground 400 bbl produced water storage tank Emissions Calculations Requsted Throughput 51100 bbl Control No Control Efficiency 0.00% Emissions Summary Table Pollutant Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 0.0287 lb/bbl 0.7333 tpy 0.7333 tpy CDPHE Benzene 0.000701 lb/bbl 35.8211 lb/yr 35.8211 lb/yr CDPHE n-Hexane 0.00315 lb/bbl 160.9650 lb/yr 160.9650 lb/yr CDPHE Note:Operator took a pressurized water sample off of the heater treater.This sample was analyzed and speciated to determine VOC content. Conservatively, 100%of the VOC in the sample was assumed to volitalize from the water through flash and W&B. Example emissions calulation: (VOC wt%) * (lbWater/yr) =(IbVOC/yr) Regulatory Review Section II.A.1 -Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A(July, 1992)) in all subsections of Section II.A and B of this regulation. Regulation 2—Odor Section I.A-No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven (7) or more volumes of odor free air. 003 One heater treater controlled by one enclosed flare that achieves a minimum control efficiency of 95%. Equipment Description This source vents natural gas from: heater treater Emissions from this source are: routed to a flare Natural gas venting from heater treater.Emissions from this source are routed to a flare. Calculations Emission Calculation Method EPA Emission Inventory Improvement Program Publication:Volume II,Chapter 10-Displacement Equation(10.4-3) Ex=Q*MW*Xx/C Ex=emissions of pollutant x Q=Volumetric flow rate/volume of gas processed MW=Molecular weight of gas=SG of gas*MW of air Xx=mass fraction of x in gas C=molar volume of ideal gas(379 scf/Ib-mol)at 60F and 1 atm Throughput(Q) 10.66 MMsd/yr 1216.894977 sd/hr MW 27.508 Ib/Ib-mol 0.029205479 MMscf/d mole% MW lbx/lbmol mass fraction lb/hr lb/yr tpy Helium 0.4900 4.0026 0.020 0.00071 0.06 551.64 0.28 CO2 2.0000 44.01 0.880 0.03200 2.83 24757.08 12.38 N2 48.1257 28.013 13.481 0.49009 43.29 379188.08 189.59 methane 28.2334 16.041 4.529 0.16464 14.54 127383.33 63.69 ethane 6.8877 30.063 2.071 0.07527 6.65 58240.42 29.12 propane 6.8715 44.092 3.030 0.11014 9.73 85217.61 42.61 isobutane 1.1277 58.118 0.655 0.02383 2.10 18434.11 9.22 n-butane 3.5339 58.118 2.054 0.07466 6.59 57767.41 28.88 isopentane 0.7239 72.114 0.522 0.01898 1.68 14683.05 7.34 n-pentane 0.9910 72.114 0.715 0.02598 2.29 20100.70 10.05 cydopentane 0.0234 70.13 0.016 0.00060 0.05 461.57 0.23 n-Hexane 0.2287 86.18 0.197 0.00716 0.63 5543.58 2.77 cydohexane 0.0530 84.16 0.045 0.00162 0.14 1254.58 0.63 Other hexanes 0.3275 86.18 0.282 0.01026 0.91 7938.45 3.97 heptanes 0.1821 100.21 0.182 0.00663 0.59 5132.62 2.57 methylcydohexane 0.0526 98.19 0.052 0.00188 0.17 1452.68 0.73 224-TMP 0.0007 114.23 0.001 0.00003 0.00 22.49 0.01 Benzene ' 0.0016 78.12 0.001 0.00005 0.00 35.16 0.02 Toluene 0.0017 92.15 0.002 0.00006 0.01 44.06 0.02 Ethylbenzene 0.0009 106.17 0.001 0.00003 0.00 26.88 0.01 Xylenes 0.0013 106.17 0.001 0.00005 0.00 38.82 0.02 C8+Heavies 0.1417 114.231 0.162 0.00588 0.52 4552.73 2.28 14.26 VOC mass frail 0.288 Total VOC(Uncontrolled) 111.35 Notes Mole%,MW,and mass fractions from Blackcomb 3-14 gas analysis collected 04/16/2015. 15LI1335.CP1.xlsm 003 One heater treater controlled by one enclosed flare that achieves a minimum control efficiency of 95%. Flaring Information Equipment Description Gas Heating Value 769 Btu/scf Throughput 8197.54 MMBtu/yr Overall Control 95.00% Combustion emission factor source: AP-42:Chapter 13.5 0.07 Ilb NOX/MMBtu 0.37 Ilb CO/MMBtu Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissions Controlled Emissions Source VOC 20892 lb/MMscf 1044.59 lb/MMscf 111.4 tpy 5.6 tpy Gas Analysis Nox 0.07 Ib/MMBTU 0.07 lb/MMBTU 0.28 tpy 0.28 tpy AP-42 CO 0.37 lb/MMBTU 0.37 lb/MMBTU 1.52 tpy 1.52 tpy AP-42 Benzene 3.30 lb/MMscf 0.16 lb/MMscf 35 lb/yr 2 lb/yr Gas Analysis n-Hexane 520.04 lb/MMscf 26.0018 lb/MMscf 5544 lb/yr 277 lb/yr Gas Analysis Toluene 4.133 lb/MMscf 0.2067 lb/MMscf 44 lb/yr 2 lb/yr Gas Analysis Xylenes 3.642 lb/MMscf 0.1821 lb/MMscf 39 lb/yr 2 lb/yr Gas Analysis Ethylbenzene 2.521 lb/MMscf 0.1261 lb/MMscf 27 lb/yr 1 lb/yr Gas Analysis Regulatory Applicability AQCC Regulation 1 This source is subject to the opacity requirements for flares in Section II.A.5:'No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30%opacity.' AQCC Regulation 2 Section LA applies to all emission sources."No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 7 Was the well newly constructed,hydraulically fractured,or recompleted on or after August 1,2014? yes This separator is subject to Reg 7,Section XVII.G.and control requirements of Reg 7,Section XVII.B.2 15LI1335.CP1.xlsm One(1)Cummins,G5.9,SN:73697045,natural gas-fired,naturally aspirated,4 stroke rich bum reciprocating internal combustion engine,site rated at 99 horsepower at 2,200 RPM.This engine shall be equipped with a non-selective catalytic reduction(NSCR)system and air-fuel ratio control. This emission unit is a pumpjack engine. 004 Engine Information Engine date of mfg 6/1/2014 Manufacturer. Cummins Model Number. G5.9 Serial Number: 73697045 RPM: 2200 Site-rated RPM: 2200 Engine Function Pump jack berating Mfg's Max.Rated Horsepower©sea level: 99 Horsepower used for calcuations: 99 BSCF©100%Load(btu/hp-hr): 8462 Site-Rated BSCF(81 100%load(btu/hp-hr): 8462 Engine Type 4SRB Other Parameters Aspiration naturally aspirated Electrical Generator Max Site Rating(kw) NA Max hrs/yr of Operation 8760 Calculations Fuel Use Rate 100%Load 1090 scf/hr ACTUAL Annual Fuel Consumption 9.54 MMscf/yr MAX rU I tN I IAL Annual Fuel Consumption 9.540 MMscf/yr REQUESTED Annual Fuel Consumption 9540 MMscf/yr Fuel Heating Value 769 btu/scf Emission Control Information This engine shall be equipped with a non-selective catalytic reduction(NSCR)system and air-fuel ratio control Emissions Summary Table Pollutant Uncontrolled Emission Factor Controlled Emission Factor Uncontrolled Emissior Controlled Emissions Source NOx 11.400 g/hp-hr 2.800 g/hp-hr 10.88 tpy 2.67 tpy Manufacturer CO 22.500 g/hp-hr 4.800 g/hp-hr 21.46 tpy 4.58 tpy Manufacturer VOC 1.500 g/hp-hr 0.020 g/hp-hr 1.43 tpy 0.02 tpy Manufacturer Formaldehyde 0.000 g/hp-hr 0.000 g/hp-hr 0 lb/yr 0 lb/yr AP-42 Acetaldehyde 0.003 Ib/MMBTU 0.003 Ib/MMBTU 21 lb/yr 21 lb/yr AP-42 Acrolein 0.003 Ib/MMBTU 0.003 Ib/MMBTU 19 lb/yr 19 lb/yr AP-42 Benzene 0.002 Ib/MMBTU 0.002 Ib/MMBTU 12 lb/yr 12 lb/yr AP-42 15LI1335.CP1.xlsm One(1)Cummins,G5.9,SN:73697045,natural gas-fired,naturally aspirated,4 stroke rich bum reciprocating internal combustion engine,site rated at 99 horsepower at 2,200 RPM.This engine shall be equipped with a non-selective catalytic reduction(NSCR)system and air-fuel ratio control. This emission unit is a pumpjack engine. 004 Regulatory Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines/No NAAQS violations expected(see Public Comment Public Comment not required MACT 7777 Facility is an area source of HAPs,so engine is not subject to major source requirements.Engine is new Reg 7 XVII.E.2 The engine is not subject to any emission standards under this regulation because the engine is Standards(g/hp-hr) less than 100 hp Reg 7 X\/II.E.3 The engine is not subject to Reg 7 XVII.E.3 because the engine is rated less than 500 hp Reg 7 XVI.B(Ozone NAA requirements) Not located in NAA so not subject to Reg 7 XVI.B applies? MACT ZZZZ(area Is this engine subject to MACT 7777 area source requirements? Yes source) Is this engine subject to NSPS JJJJ? 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M .. o 71 Z W p c ,O, 4 pp o ea E z 41 0 co y cmd y 0 O "..5-, y .0 0 O c v a 0 U E a 7 C 3 C7 a U A " ar �_ o x •C '�' 0 E c%D a - 0 E O 'k " E O o a O a w c%� c..) a w re) w° z 3 rii Q O ® O O O O P, ® w \\, • AIR POLLUTANT EMISSION NOTICE(APEN)&Application for Construction Permit—tt Natural Gas Venting' Permit Number: I 5(....1 I 3 3S Emission Source AIRS Ill: o3-3 /0154 / 0.3 Section 05—Stack Information(Combustion stacks must be listed here) Section 06-Stack(Source,If no combustion)Location(Datum&either Lat/Long or UTM) Stack Discharge Operator Stack Base Horizontal Datum UTM UTM Fasting or UTM Northing or Method of Collection for Height Above Temp Flow Rate Velocity) Moisture Stack Elevation Ground Level (°F) (ACFM) (ftisec (%) (NAD27,NAD83, Zone Longitude Latitude Location Data(e.g map, ID No (feet) (feet) WGS84) (12 or 13) (meters or degrees) (meters or degrees) CPS.Googlefarthl 5,219 25 1000 Unk. Unk. 90 NAD83 -103.40923 39.53409 COGCC Direction of stack outlet(check one): ® Vertical O Vertical with obstructing raincap ❑ Horizontal ❑ Down ❑ Other(Describe): Exhaust Opening Shape&Size(check one): ® Circular:Inner Diameter(inches)= 48" ❑ Other Length(inches)= Width(inches)= Section 07—Control Device Information ❑ VRU used for control of: ® Combustion Device used for control of Heater-treater/separator Rating: 4.49 MMBtuAv Size: Make/Model: Type (1) Enclosed Make/Model/Serial#: Lead;L30-0011;SN: Combustor 25429 Requested VOC&HAP Control Efficiency: % VOC&HAP Control Efficiency: Requested: 95 % Manufacturer Guaranteed: 98 % Annual time that VRU is bypassed(emissions vented): % Minimum temp.to achieve requested control: °F Waste gas heat content- 769 Btu/scf The VRU recycles venting emissions to: Constant pilot light? ® Yes ❑ No Pilot burner rating: 0.04 MMBtu/hr ❑ Describe Any Other Section 08—Emissions inventory Information&Emission Control Information Attach any emission calculations and emission factor documentation to this APEN form, la Emission Factor Documentation attached Data rear for actual calemda yr.emissions below&throughput above(e.g.20071:I 2015 Actual Calendar Year Estimation Control Device Description Overall Control Emission Factor Emissions' Permitted Emissions Method or Pollutant Collection Efficiency Uncontrolled Uncontrolled Controlled Uncontrolled Controlled Emission Primary Secondary Efficiency (%Reduction) Basis Units (Tons/Year) (Tons/Year) (Tons/Year) (Tons/Year) Factor Source VOC ECD N/A 100% 95% 2.09E+04 Ibs/MMscf 92.76 - 4.64. 111.31 - 5.57' See Calcs NOx N/A N/A N/A N/A 0.068 lb/MM Btu 0.28- 0.28 0.28 - 0.28 AP-42 CO N/A N/A N/A N/A 0.37 lb/MMBtu 1.52- 1.52 1.52 - 1.52 AP-42 SOx N/A N/A N/A N/A 2.195 Ib/MMscf 0.01 - 0.01 0.01 - 0.01 AP-42 Benzene ECD N/A 100% 95% 3.29E+00 Ibs/MMscf 0.01 --" 0.00- 0.02 - 0.00 ' See Coles Toulene ECD N/A 100% 95% 4.13E+00 Ibs/MMscf 0.02 - 0.00- 0.02 - (1.00- Sec Calcs Ethylbenzene ECD N/A 100% 95% 2.52E+00 Ibs/MMscf 0.01.." 0.00 i 0.01 — 0.00 ' See Coles Xylene ECD N/A 100% 95% 3.64E+00 Ibs/MMscf 0.02 - 0.00- 0.02 ' 0.00- See Coles n-Hexane ECU N/A 100% 95% 5.19E+02 Ibs/MMscf 2.31 - 0.12 - 2.77 — 0.14 , See Coles Please use the APCD Non-Criteria Reportable Air Pollutant Addendum form to report pollutants not listed above. 'You will be charged an additional APEN!coif APEN is tilled oat incorrectly or missing information and requires re-submittal. 'Annual emission fees will be based on actual emissions reported here, Section D9— nt minion-i hereby certify that sill informati n contained herein and information submitted with this application is complete,true and correct. fJ�/ .IoeRczendes Production Engineer Signature o Legal uttionzed to Supply Data Date Name of Legally Authorized Person(Please print) Title FO APCD-21 Page 2 o12 Natural Gros Venting APEN-Blackcomb 3-14 . RFC v 'CEP 2 8 2015 ti Stain. Sa . Hello