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Home My WebLink About20140560.tiff STATE OF COLORADO John W.Hickenlooper,Governor pF cps Larry Wolk, MD,MSPH Executive Director and Chief Medical Officer (ti/ �'�j p. Dedicated to protecting and improving the health and environment of the people of Colorado 4300 Cherry Creek Dr.S. Laboratory Services Division \e 6/ Denver,Colorado 80246-1530 8100 Lowry Blvd. Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Weld County Clerk&Recorder 1402 N 17th Ave Greeley, CO 80631 February 14, 2014 Dear Sir or Madam: On February 17, 2014,the Air Pollution Control Division will publish a public notice for Continental Resources Inc — Wallach 1-8H, in the l he Greeley Tribune. A copy of this public notice and the public comment packet are enclosed. Thank you for assisting the Division by posting a copy of this public comment packet in your office. Public copies of these documents are required by Colorado Air Quality Control Commission regulations. The packet must be available for public inspection for a period of thirty (30) days from the date the public notice is published. Please send any comment regarding this public notice to the address below. Colorado Dept. of Public Health & Environment APCD-SS-B I 4300 Cherry Creek Drive South Denver, Colorado 80246-1530 Attention: Clara Gonzales Regards, i 1 L2i Clara Gonzales RECEIVED Public Notice Coordinator Stationary Sources Program FEB 2 1 2O14 Air Pollution Control Division WIELD COMITY Enclosure COMMISSIONERS LtcH CSRL) L �a I� 2014-0560 a- aLi) • W STATE OF COLORADO John W.Hickenlooper,Governor Larry Wolk, MD,MSPH of• LCOLD Executive Director and Chief Medical Officer A44. ¢ ' Dedicated to protecting and improving the health and environment of the people of Colorado * * e bt 4300 Cherry Creek Dr.S. Laboratory Services Division » Denver,Colorado 80246-1530 8100 Lowry Blvd. gate Phone(303)692-2000 Denver,Colorado 80230-6928 Colorado Department Located in Glendale,Colorado (303)692-3090 of Public Health www.colorado.gov/cdphe and Environment Website Title: Continental Resources Inc— Wallach 1-8H—Weld County Released To: The Greeley Tribune On: February 14, 2014 Published: February 17. 2014 PUBLIC NOTICE OF A PROPOSED PROJECT OR ACTIVITY WARRANTING PUBLIC COMMENT Notice is hereby given that an application for a proposed project or activity has been submitted to the Colorado Air Pollution Control Division for the following source of air pollution: Applicant: Continental Resources Inc Facility: Wallach I-8H Wellpad Section 8 T7N R6 1 W Weld County The proposed project or activity is as follows: Continental Resources in operating a wellhead facility in Weld County. The Division has determined that this permitting action is subject to public comment per Colorado Regulation No. 3, Pan B, Section tII.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 13WE2929 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 www.colorado.gov/cdphe/AirPublicNotices The Division hereby solicits submission of public comment from any interested person concerning the ability of the proposed project or activity to comply with the applicable standards and regulations of the Commission. The Division will receive and consider written public comments for thirty calendar days after the date of this Notice. Any such comment must be submitted in writing to the following addressee: Peter Armington Colorado Department of Public Health and Environment 4300 Cherry Creek Drive South,APCD-SS-BI Denver, Colorado 80246-1530 cdphe.commentsapcd@state.co.us x . p STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT V: AIR POLLUTION CONTROL DIVISION *;\ ;Y:2447: TELEPHONE: (303) 692-3150 : Is CONSTRUCTION PERMIT PERMIT NO: 13WE2929 Issuance 1 DATE ISSUED: ISSUED TO: Continental Resources, Inc. THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS: Oil and gas facility, known as the Wallach 1-8H, located in Section 8, T7N, R61W, in Weld County, Colorado. THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Description Equipment ID Point One (1) Caterpillar, Model G3306, Serial Number R6S00565, natural gas-fired, naturally aspirated, 4SRB reciprocating internal combustion engine, site rated at 145 001 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. Three (3) 400 BBL fixed roof storage tanks used to store Oil Tanks 002 crude oil. Emissions from these tanks are controlled by an enclosed flare One (1) 400 BBL fixed roof storage tanks used to store PW Tank 003 produced water. Emissions from these tanks are controlled by an enclosed flare. Separator & Separator controlled by an enclosed flare. Flare has a Treater Gas 004 minimum combustion efficiency of 95%. Point 001: This engine may be replaced with another engine in accordance with the temporary engine replacement provision or with another Caterpillar G3306 engine in accordance with the permanent replacement provision of the Alternate Operating Scenario (AOS), included in this permit as Attachment A. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND AIRS ID: 12319C04 Page 1 of 16 Col do p e o Public Health and Environment Air Pollution Control Division CONTROL ACT C.R.S. (25-7-101 et seq), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS: REQUIREMENTS TO SELF-CERTIFY FOR FINAL AUTHORIZATION 1. YOU MUST notify the Air Pollution Control Division (the Division) no later than fifteen days after issuance of this permit, by submitting a Notice of Startup form to the Division. The Notice of Startup form may be downloaded online at www.cdphe.state.co.us/ap/downloadforms.html. Failure to notify the Division of startup of the permitted source is a violation of Air Quality Control Commission (AQCC) Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2. Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained in this permit shall be demonstrated to the Division. It is the owner or operator's responsibility to self-certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit. (Reference: Regulation No. 3, Part B, III.G.2). 3. This permit shall expire if the owner or operator of the source for which this permit was issued: (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction permit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, III.F.4.b. (Reference: Regulation No. 3, Part B, I I I.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 Emission Type Equipment ID Point NO VOC CO x 001 1.4 0.7 1.4 Point Oil Tanks 002 --- 2.7 --- Point PW Tank 003 --- 0.3 --- Point Separator& 004 1.1 8.8 6.0 Point Treater Gas See "Notes to Permit Holder"for information on emission factors and methods used to calculate limits. 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 AIRS ID: 123/9C04 Page 2 of 16 Col do ; pgrhe of Public Health and Environment Air Pollution Control Division 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. 6. 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 001 Catalyst NOx, CO, VOC Oil Tanks 002 Flare VOC PW Tanks 003 Flare VOC Separator& 004 Flare VOC Treater Gas PROCESS LIMITATIONS AND RECORDS 7. This source shall be limited to the following maximum processing rates as listed below. Monthly records of the actual processing rate shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits Facility AIRS Equipment Point Process Parameter Annual Limit ID 001 Consumption of natural gas as a fuel 10.21 MMscf/yr Oil Tanks 002 Crude oil throughput 18,738 bbl/yr PW Tank 003 Produced water throughput 42,000 bbl/yr Separator& 004 Natural gas flaring 12.12 MMscf/yr Treater Gas 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. 8. Records shall be kept in either an electronic file or hard copy provided that they can be promptly supplied to the Division upon request. All records shall be retained for a consecutive period of three years. STATE AND FEDERAL REGULATORY REQUIREMENTS AIRS ID: 123/9C04 Page 3 of 16 Co do p e o Public PollutionHealthand ControlEnvironment Division 9. The permit number and AIRS ID point number (e.g. 123/4567/890) shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E.) (State only enforceable) 10. 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.) 11. This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 12. Points 002-004: Minor sources in designated nonattainment or attainment/maintenance areas that are otherwise not exempt pursuant to Section II.D. of Regulation No. 3, Part B, shall apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is nonattainment or attainment/maintenance. This source shall meet the requirements to apply RACT and reduce emissions by installing and operating an enclosed flare (Reference: Regulation No. 3, Part B, III.D.2.a). OPERATING & MAINTENANCE REQUIREMENTS 13. Points 002-004: Upon startup of these points, the owner or operator shall follow the most recent operating and maintenance (O&M) plan and record keeping format approved by the Division, in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III.G.7.) COMPLIANCE TESTING AND SAMPLING Periodic Testing Requirements 14. Point 001: This engine is subject to the periodic testing requirements as specified in the operating and maintenance (O&M) plan as approved by the Division. Revisions to your O&M plan are subject to Division approval. Replacements of this unit completed as Alternative Operating Scenarios may be subject to additional testing requirements as specified in Attachment A. 15. Point 004: On an annual basis, the operator shall complete a site specific extended gas analysis of the natural gas produced at this site that is routed to the flare in order to verify the VOC content (weight fraction) of this emission stream used in the permit application. Results of testing shall be used to determine site-specific emission factors using Division approved methods. ADDITIONAL REQUIREMENTS 16. A revised Air Pollutant Emission Notice (APEN) shall be filed: (Reference: Regulation No. 3, Part A, II.C) a. Annually by April 301h whenever a significant increase in emissions occurs as follows: AIRS ID: 123/9C04 Page 4 of 16 Co A.do • p§rt a yo Public Health and Environment • Air Pollution Control Division .tJ For any criteria pollutant: For sources emitting less than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN; or For volatile organic compounds (VOC) and nitrogen oxides sources (NO,) in ozone nonattainment areas emitting less than 100 tons of VOC or NOx per year, a change in annual actual emissions of one (1) ton per year or more or five percent, whichever is greater, above the level reported on the last APEN; or For sources emitting 100 tons per year or more, a change in actual emissions of five percent or 50 tons per year or more, whichever is less, above the level reported on the last APEN submitted; or For any non-criteria reportable pollutant: If the emissions increase by 50% or five (5) tons per year, whichever is less, above the level reported on the last APEN submitted to the Division. b. Whenever there is a change in the owner or operator of any facility, process, or activity; or c. Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d. Whenever a permit limitation must be modified; or e. No later than 30 days before the existing APEN expires. f. Within 14 calendar days of commencing operation of a permanent replacement engine under the alternative operating scenario outlined in this permit as Attachment A. The APEN shall include the specific manufacturer, model and serial number and horsepower of the permanent replacement engine, the appropriate APEN filing fee and a cover letter explaining that the owner or operator is exercising an alternative-operating scenario and is installing a permanent replacement engine. 17. Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition. Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS: 18. 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. 19. If this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise, the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section AIRS ID: 123/9C04 Page 5 of 16 Col do p e o Pu and Environment D Airblic PollutionHealth Control Division 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. 20. 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. 21. 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. 22. 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. 23. 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. 24. 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: Peter Armington Permit Engineer Permit History Issuance Date Description Issuance 1 This Issuance Issued to Continental Resources, Inc. AIRS ID: 12319C04 Page 6 of 16 Col& do pe e 0Public Health and Environment ,. Air Pollution Control Division AIRS ID: 12319C04 Page 7 of 16 Co do �p e o Public Health and Environment ll 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: http://www.colorado qov/cs/Satellite?c=Document C&childpaeename=CDPHE- Main%2FDocument C%2FCBONAddLinkView&cid=1251599389641&pagename=CBONWrapper 4) The following emissions of non-criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. Uncontrolled Are the Controlled AIRS Pollutant CAS# BIN Emission emissions Emission Point Rate reportable? Rate(Ib/yr) (Ib/yr) Formaldehyde 5000 A 214 Yes 214 Methanol 67561 C 32 No 32 Acetaldehyde 75070 A 29 No 29 001 Acrolein 107028 A 27 No 27 Benzene 71432 A 16 No 16 1,3-Butadiene 106990 A 7 No 7 Toluene 108883 C 6 No 6 Benzene 71432 A 202 Yes 10 002 n-Hexane 110543 C 1192 Yes 60 Benzene 71432 A 294 Yes 15 003 n-Hexane 110543 C 924 No 46 Benzene 71432 A 1824 Yes 91 Toluene 108883 C 4155 Yes 208 004 Ethylbenzene 100414 C 3361 Yes 168 Xylenes 1130207 C 7911 Yes 396 n-Hexane 110543 C 6945 Yes 347 AIRS ID: 123/9C04 Page 8 of 16 Col', ''do p e o Public Health and Environment Air Pollution Control Division Ott' m 5) The emission levels contained in this permit are based on the following emission factors: Point 001: Emission Factors - Emission Factors— Uncontrolled Controlled CAS Pollutant lb/MMBtu g/bhp-hr lb/MMBtu g/bhp-hr NOx 2.9305 10.9000 0.2689 1.0000 CO 3.5220 13.1000 0.2689 1.0000 VOC 0.5915 2.2000 0.1344 0.5000 5000 Formaldehyde 0.0205 0.0762 0.0205 0.0762 67561 Methanol 0.0031 0.0114 0.0031 0.0114 75070 Acetaldehyde 0.0028 0.0104 0.0028 0.0104 107028 Acrolein 0.0026 0.0098 0.0026 0.0098 71432 Benzene 0.0016 0.0059 0.0016 0.0059 106990 1,3-Butadiene 0.0007 0.0025 0.0007 0.0025 108883 Toluene 0.0006 0.0021 0.0006 0.0021 Emission factors are based on a Brake-Specific Fuel Consumption Factor of 8200 Btu/hp-hr, a site-rated horsepower value of 145, and a fuel heat value of 1020 Btu/scf. Emission Factor Sources: CAS Pollutant Uncontrolled EFSource Controlled EF Source NOx Email from Great Plains Gas Email from Great Plains Gas Compression Compression CO Email from Great Plains Gas Email from Great Plains Gas Compression Compression VOC Email from Great Plains Gas Email from Great Plains Gas Compression Compression 5000 Formaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 67561 Methanol AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 75070 Acetaldehyde AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 107028 Acrolein AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 71432 Benzene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 106990 1,3-Butadiene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas 108883 Toluene AP-42; Table 3.2-3 (7/2000); No Control Natural Gas Point 002: Emission Factors Emission Factors CAS # Pollutant Uncontrolled Controlled Source lb/BBL Oil lb/BBL Oil Throughput Throughput VOC 5.365 0.268 E&P TANK 110543 n-Hexane 0.0636 0.00318 E&P TANK 71432 Benzene 0.0108 0.00054 E&P TANK Note: The controlled emissions factors for point 002 are based on the flare control efficiency of 95%. AIRS ID: 123/9C04 Page 9 of 16 Co do p e o Public Health ti and Control nment III Air Pollution Control Division Point 003: Emission Factors Emission Factors CAS# Pollutant Uncontrolled Controlled Source lb/BBL Produced lb/BBL Produced Water Throughput Water Throughput VOC 0.262 0.013 CDPHE 110543 n-Hexane 0.022 0.0011 CDPHE 71432 Benzene 0.007 0.00035 CDPHE Note: The controlled emissions factors for point 003 are based on the flare control efficiency of 95%. Point 004: Weight Emission Emission CAS# Pollutant Fraction of Factors Factors Source Gas(%) Uncontrolled Controlled NOx 0.068 0.068 AP-42 lb/MMBtu lb/MMBtu CO --- 0.37 lb/MMBtu 0.37 AP-42 lb/MMBtu VOC 38.85 26,650 1332.5 Engineering lb/mmscf lb/mmscf Calculation 71432 Benzene 0.2 150.5 7.5 lb/mmscf Engineering lb/mmscf Calculation 108883 Toluene 0.5 342.8 17.1 Engineering lb/mmscf lb/mmscf Calculation 277.3 13.9 Engineering 100414 Ethylbenzene 0.4 lb/mmscf lb/mmscf Calculation 1330207 Xylenes 1.0 652.7 32.6 Engineering lb/mmscf lb/mmscf Calculation 110543 n-hexane 0.8 573.0 28.6 Engineering lb/mmscf lb/mmscf Calculation Note: The uncontrolled VOC and HAP emissions for this point were calculated using the 8/19/2013 analysis of a gas sample collected from the Wallach 1-8H well. 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 engine is subject to 40 CFR, Part 60, Subpart JJJJ—Standards of Performance for Stationary Spark Ignition Internal Combustion Engines (See January 18, 2008 Federal Register posting—effective March 18, 2008). This rule has not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 6. A copy of the complete subpart is available on the EPA website at: htto://www.eoa.aov/ttn/atw/area/fr18ia08.pdf 8) This engine is subject to 40 CFR, Part 63, Subpart Z777 - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines. (See January 18, 2008 Federal Register posting - effective March 18, 2008). The January 18, 2008 amendments to AIRS ID: 123/9C04 Page 10 of 16 Col do • p " e oPublic Health and Environment Air Pollution Control Division include requirements for area sources and engines < 500 hp located at major sources have not yet been incorporated into Colorado Air Quality Control Commission's Regulation No. 8. A copy of the complete subpart is available on the EPA website at: http://www.epa.qov/ttn/atw/area/fr18ia08.pdf Additional information regarding area source standards can be found on the EPA website at: http://www.epa.qov/ttn/atw/area/arearules.html 9) This engine is subject to 40 CFR, Part 63, Subpart ZZZZ - National Emission Standards for Hazardous Air Pollutants for Reciprocating Internal Combustion Engines (See August 20, 2010 Federal Register posting -effective October 19, 2010). The August 20, 2010 amendments to include 10) This facility is classified as follows: Applicable Status Requirement Operating Permit Synthetic Minor Source of: VOC NANSR Synthetic Minor Source of: VOC MACT ZZZZ Area Source Requirements: Not Applicable 11) 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 12) An Oil and Gas Industry Construction Permit Self-Certification Form is included with this permit packet. Please use this form to complete the self-certification requirements as specified in the permit conditions. Further guidance on self-certification can be found on our website at: www.colorado-qov/cdphe/oilgaspermits AIRS ID: 123/9C04 Page 11 of 16 Co do p e o Public PollutionHealthand Control DivisionEnvironment ATTACHMENT A: ALTERNATIVE OPERATING SCENARIOS RECIPROCATING INTERNAL COMBUSTION ENGINES October 12, 2012 2. Alternative Operating Scenarios The following Alternative Operating Scenario (AOS) for the temporary and permanent replacement of natural gas fired reciprocating internal combustion engines has been reviewed in accordance with the requirements of Regulation No. 3., Part A, Section IV.A, Operational Flexibility-Alternative Operating Scenarios, Regulation No. 3, Part B, Construction Permits, and Regulation No. 3, Part D, Major Stationary Source New Source Review and Prevention of Significant Deterioration, and it has been found to meet all applicable substantive and procedural requirements. This permit incorporates and shall be considered a Construction Permit for any engine replacement performed in accordance with this AOS, and the owner or operator shall be allowed to perform such engine replacement without applying for a revision to this permit or obtaining a new Construction Permit. 2.1 Engine Replacement The following AOS is incorporated into this permit in order to deal with a compressor engine breakdown or periodic routine maintenance and repair of an existing onsite engine that requires the use of either a temporary or permanent replacement engine. "Temporary is defined as in the same service for 90 operating days or less in any 12 month period. "Permanent" is defined as in the same service for more than 90 operating days in any 12 month period. The 90 days is the total number of days that the engine is in operation. If the engine operates only part of a day, that day shall count as a single day towards the 90 day total. The compliance demonstrations and any periodic monitoring required by this AOS are in addition to any compliance demonstrations or periodic monitoring required by this permit. All replacement engines are subject to all federally applicable and state-only requirements set forth in this permit (including monitoring and record keeping). The results of all tests and the associated calculations required by this AOS shall be submitted to the Division within 30 calendar days of the test or within 60 days of the test if such testing is required to demonstrate compliance with NSPS or MACT requirements. Results of all tests shall be kept on site for five (5)years and made available to the Division upon request. The owner or operator shall maintain a log on-site and contemporaneously record the start and stop date of any engine replacement, the manufacturer, date of manufacture, model number, horsepower, and serial number of the engine(s) that are replaced during the term of this permit, and the manufacturer, model number, horsepower, and serial number of the replacement engine. In addition to the log, the owner or operator shall maintain a copy of all Applicability Reports required under section 2.1.2 and make them available to the Division upon request. 2.1.1 The owner or operator may temporarily replace an existing compressor engine that is subject to the emission limits set forth in this permit with an engine that is of the same manufacturer, model, and horsepower or a different manufacturer, model, or horsepower as the existing engine without modifying this permit, so long as the temporary replacement engine complies with all permit limitations and other requirements applicable to the existing engine. Measurement of emissions from the temporary replacement engine shall be made as set forth in section 2.2. AIRS ID: 12319C04 Page 12 of 16 Col do p e o Public Health and Environment Air Pollution Control Division 2.1.2 The owner or operator may permanently replace the existing compressor engine with another engine with the same manufacturer, model, and horsepower engines without modifying this permit so long as the permanent replacement engine complies with all permit limitations and other requirements applicable to the existing engine as well as any new applicable requirements for the replacement engine. Measurement of emissions from the permanent replacement engine and compliance with the applicable emission limitations shall be made as set forth in section 2.2. An Air Pollutant Emissions Notice (APEN) that includes the specific manufacturer, model and serial number and horsepower of the permanent replacement engine shall be filed with the Division for the permanent replacement engine within 14 calendar days of commencing operation of the replacement engine. The APEN shall be accompanied by the appropriate APEN filing fee, a cover letter explaining that the owner or operator is exercising an alternative operating scenario and is installing a permanent replacement engine, and a copy of the relevant Applicability Reports for the replacement engine. Example Applicability Reports can be found at http://www.cdphe.state.co.us/ap/oilgaspermitting.html. This submittal shall be accompanied by a certification from the Responsible Official indicating that"based on the information and belief formed after reasonable inquiry, the statements and information included in the submittal are true, accurate and complete". This AOS cannot be used for permanent engine replacement of a grandfathered or permit exempt engine or an engine that is not subject to emission limits. The owner or operator shall agree to pay fees based on the normal permit processing rate for review of information submitted to the Division in regard to any permanent engine replacement. 2.2 Portable Analyzer Testing Note: In some cases there may be conflicting and/or duplicative testing requirements due to overlapping Applicable Requirements. In those instances, please contact the Division Field Services Unit to discuss streamlining the testing requirements. Note that the testing required by this Condition may be used to satisfy the periodic testing requirements specified by the permit for the relevant time period (i.e. if the permit requires quarterly portable analyzer testing, this test conducted under the AOS will serve as the quarterly test and an additional portable analyzer test is not required for another three months). The owner or operator may conduct a reference method test, in lieu of the portable analyzer test required by this Condition, if approved in advance by the Division. The owner or operator shall measure nitrogen oxide (NOX) and carbon monoxide (CO) emissions in the exhaust from the replacement engine using a portable flue gas analyzer within seven (7) calendar days of commencing operation of the replacement engine. All portable analyzer testing required by this permit shall be conducted using the Division's Portable Analyzer Monitoring Protocol (ver March 2006 or newer) as found on the Division's web site at: h ttp://www.co t o ra d o.q ov/cs/S ate l I ite/C D P H E-A P/C B O N/125159652 0270. Results of the portable analyzer tests shall be used to monitor the compliance status of this unit. For comparison with an annual (tons/year) or short term (lbs/unit of time) emission limit, the results of the tests shall be converted to a lb/hr basis and multiplied by the allowable operating hours in the month or year (whichever applies) in order to monitor compliance. If a source is not limited in its hours of operation the test results will be multiplied by the maximum number of hours in the month or year (8760), whichever applies. AIRS ID: 123/9O04 Page 13 of 16 Co do p e o Public Health and Environment Air Pollution Control Division For comparison with a short-term limit that is either input based (lb/mmBtu), output based (g/hp-hr) or concentration based (ppmvd @ 15% 02) that the existing unit is currently subject to or the replacement engine will be subject to, the results of the test shall be converted to the appropriate units as described in the above-mentioned Portable Analyzer Monitoring Protocol document. If the portable analyzer results indicate compliance with both the NOX and CO emission limitations, in the absence of credible evidence to the contrary, the source may certify that the engine is in compliance with both the NOX and CO emission limitations for the relevant time period. Subject to the provisions of C.R.S. 25-7-123.1 and in the absence of credible evidence to the contrary, if the portable analyzer results fail to demonstrate compliance with either the NOX or CO emission limitations, the engine will be considered to be out of compliance from the date of the portable analyzer test until a portable analyzer test indicates compliance with both the NOX and CO emission limitations or until the engine is taken offline. 2.3 Applicable Regulations for Permanent Engine Replacements 2.3.1 Reasonably Available Control Technology (RACT): Reg 3, Part B § II.D.2 All permanent replacement engines that are located in an area that is classified as attainment/maintenance or nonattainment must apply Reasonably Available Control Technology (RACT) for the pollutants for which the area is attainment/maintenance or nonattainment. Note that both VOC and NOX are precursors for ozone. RACT shall be applied for any level of emissions of the pollutant for which the area is in attainment/maintenance or nonattainment, except as follows: In the Denver Metropolitan PM10 attainment/maintenance area, RACT applies to PM10 at any level of emissions and to NOX and SO2, as precursors to PM10, if the potential to emit of NOX or SO2 exceeds 40 tons/yr. For purposes of this AOS, the following shall be considered RACT for natural gas fired reciprocating internal combustion engines: VOC: The emission limitations in NSPS JJJJ CO: The emission limitations in NSPS JJJJ NOX: The emission limitations in NSPS JJJJ 502: Use of natural gas as fuel PM10: Use of natural gas as fuel As defined in 40 CFR Part 60 Subparts GG (§60.331) and 40 CFR Part 72 (§ 72.2), natural gas contains 20.0 grains or less of total sulfur per 100 standard cubic feet. 2.3.2 Control Requirements and Emission Standards: Regulation No. 7, Sections XVI. and XVII.E (State- Only conditions). Control Requirements: Section XVI Any permanent replacement engine located within the boundaries of an ozone nonattainment area is subject to the applicable control requirements specified in Regulation No. 7, section XVI, as specified below: Rich burn engines with a manufacturer's design rate greater than 500 hp shall use a non- selective catalyst and air fuel controller to reduce emission. Lean burn engines with a manufacturer's design rate greater than 500 hp shall use an oxidation catalyst to reduce emissions. AIRS ID: 123/9C04 Page 14 of 16 Col 'do p9rt e o Public Health and Environment Air Pollution Control Division The above emission control equipment shall be appropriately sized for the engine and shall be operated and maintained according to manufacturer specifications. The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. Emission Standards: Section XVII.E— State-only requirements Any permanent engine that is either constructed or relocated to the state of Colorado from another state, after the date listed in the table below shall operate and maintain each engine according to the manufacturer's written instructions or procedures to the extent practicable and consistent with technological limitations and good engineering and maintenance practices over the entire life of the engine so that it achieves the emission standards required in the table below: Construction or Emission Standards in G/hp-hr Max Engine HP Relocation Date NOx CO VOC January 1, 2008 2.0 4.0 1.0 100<Hp<500 January 1, 2011 1.0 2.0 0.7 July 1, 2007 2.0 4.0 1.0 500<Hp July 1, 2010 1.0 2.0 0.7 The source shall submit copies of the relevant Applicability Reports required under Condition 2.1.2. 2.3.3 NSPS for stationary spark ignition internal combustion engines: 40 CFR Part 60, Subpart JJJJ A permanent replacement engine that is manufactured on or after 7/1/09 for emergency engines greater than 25 hp, 7/1/2008 for engines less than 500 hp, 7/1/2007 for engines greater than or equal to 500 hp except for lean burn engines greater than or equal to 500 hp and less than 1,350 hp, and 1/1/2008 for lean burn engines greater than or equal to 500 hp and less than 1,350 hp are subject to the requirements of 40 CFR Part 60, Subpart JJJJ. An analysis of applicable monitoring, recordkeeping, and reporting requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the NSPS is in addition to that required by this AOS. Note that the initial test required by NSPS Subpart JJJJ can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. Note that under the provisions of Regulation No. 6. Part B, section I.B. that Relocation of a source from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of Regulation No. 6 (i.e., the date that the source is first relocated to Colorado becomes equivalent to the manufacture date for purposes of determining the applicability of NSPS JJJJ requirements). However, as of October 1, 2011 the Division has not yet adopted NSPS JJJJ. Until such time as it does, any engine subject to NSPS will be subject only under Federal law. Once the Division adopts NSPS JJJJ, there will be an additional step added to the determination of the NSPS. Under the provisions of Regulation No. 6, Part B, § 1.8 (which is referenced in Part A), any engine relocated from outside of the State of Colorado into the State of Colorado is considered to be a new source, subject to the requirements of NSPS JJJJ. 2.3.4 Reciprocating internal combustion engine (RICE) MACT: 40 CFR Part 63, Subpart ZZZZ A permanent replacement engine located at either an area or major source is subject to the requirements in 40 CFR Part 63, Subpart ZZZZ. An analysis of the applicable monitoring, recordkeeping, and reporting AIRS ID: 123/9C04 Page 15 of 16 Co do p e o Pu and Environment D Airblic PollutionHealth Control Division requirements for the permanent engine replacement shall be included in the Applicability Reports required under Condition 2.1.2. Any testing required by the MACT is in addition to that required by this AOS. Note that the initial test required by the MACT can serve as the testing required by this AOS under Condition 2.2, if approved in advance by the Division, provided that such test is conducted within the time frame specified in Condition 2.2. 2.4 Additional Sources The replacement of an existing engine with a new engine is viewed by the Division as the installation of a new emissions unit, not "routine replacement" of an existing unit. The AOS is therefore essentially an advanced construction permit review. The AOS cannot be used for additional new emission points for any site; an engine that is being installed as an entirely new emission point and not as part of an AOS- approved replacement of an existing onsite engine has to go through the appropriate Construction/Operating permitting process prior to installation. AIRS ID: 123/9C04 Page 16 of 16 Construction Permit Application Preliminary Analysis Summary Section 1 —Applicant Information Company Name: Continental Resources, Inc. Permit Number: 13WE2929 Source Location: Section 9 T7N R61W,Weld County Equipment Description: Point 002: Three 400 bbl oil storage tanks Point 003: One 400 bbl water storage tank AIRS ID: 12319C04/002-003 Date: January 15, 2014 Review Engineer: Peter Armington Control Engineer: Stefanie Rucker Section 2—Action Completed Grandfathered Modification APEN Required/Permit Exempt X Initial Approval Transfer of Ownership APEN Exempt/Permit Exempt * If tank is a true minor source at a true minor facility, it may be granted "Final Approval"without first being issued an Initial Approval permit Section 3—Applicant Completeness Review Was the correct APEN submitted for this source type? X Yes No Is the APEN signed with an original signature? X Yes No Was the APEN filled out completely? X Yes No Did the applicant submit all required paperwork? X Yes No Did the applicant provide ample information to determine emission rates? X Yes No If you answered"no" to any of the above, when did you mail an Information Request letter to the source? On what date was this application complete? September 26, 2013 Section 4—Source Description AIRS Point Equipment Description 002 Three (3)400 bbl oil storage tanks 003 One (1) above ground 400 bbl atmospheric produced water storage tank Are "flash" emissions anticipated from these tanks? X Yes No Is this tank located at an E&P site? X Yes No Is this tank located at a non-E&P, midstream or Yes X No downstream site? Is this a portable source? Yes X No Is this location in a non-attainment area for any criteria X Yes No pollutant? If"yes", for what pollutant? PM10 CO X Ozone Is this location in an attainment maintenance area for Yes X No any criteria pollutant? Page 1 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 claiming exempt status for this source based on the fraction of oil in the stored water(less Yes X No than 1% by volume crude oil on an average annual basis)? Are these produced water tanks located at a commercial facility that accepts oil production Yes X No wastewater for processing? Are these produced water tanks subject to Colorado Oil and Gas Conservation Commission (COGCC) 805 Yes X No Rule? Section 5—Emission Estimate Information AIRS Point Emission Factor Source 002 E&P TANK 003 CDPHE Produced Water Storage Tank Emission Factors; CDPHE Memo 09-02 Did the applicant provide actual process data for the emission inventory? Yes X No Basis for Potential to Emit(PTE) AIRS Point Process Consumption/Throughput/Production 002 18,738 BBL per year oil 003 42,000 BBL per year wastewater Basis for Actual Emissions Reported During this APEN Filing (Reported to Inventory) AIRS Point Process Consumption/Throughput/Production Data Year 002 NA 003 NA Basis for Permitted Emissions(Permit Limitsj AIRS Point Process Consumption/Throughput/Production 002 18,738 BBL per year oil 003 42,000 BBL per year wastewater Does this source use a control device? X Yes No % Reduction AIRS Point Process Control Device Description Granted 002 01 Flare 95 003 01 Flare 95 Section 6—Emission Summary (tons per year) See History File Section 7—Non-Criteria/Hazardous Air Pollutants See History File Section 8—Testing Requirements Will testing be required to show compliance with any emission rate or regulatory Yes X No standard? Page 2 Section 9—Source Classification Is this a new previously un-permitted source? X Yes No What is this facility classification? True X Synthetic Major Minor Minor Classification relates to what programs? X Title V PSD X NA NSR MACT Is this a modification to an existing permit? Yes X No If"yes" what kind of modification? Minor Synthetic Major Minor Section 10— Public Comment Does this permit require public comment per CAQCC Regulation 3? X Yes No If"yes", for which pollutants?Why? 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)? AIRS Point Section 12— Regulatory Review Regulation 1 - Particulate, Smoke, Carbon Monoxide and Sulfur Dioxide Section II.A.1 - Except as provided in paragraphs 2 through 6 below, no owner or operator of a source shall allow or cause the emission into the atmosphere of any air pollutant which is in excess of 20% opacity. This standard is based on 24 consecutive opacity readings taken at 15-second intervals for six minutes. The approved reference test method for visible emissions measurement is EPA Method 9 (40 CFR, Part 60, Appendix A (July, 002,003 1992)) in all subsections of Section II. A and B of this regulation. Section II.A.5 -Smokeless Flare or Flares for the Combustion of Waste Gases No owner or operator of a smokeless flare or other flare for the combustion of waste gases shall allow or cause emissions into the atmosphere of any air pollutant which is in excess of 30% opacity for a period or periods aggregating more than six minutes in any sixty consecutive minutes. Regulation 2—Odor Section I.A - No person, wherever located, shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are 002,003 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: 002,003 each individual emission point in a nonattainment area with uncontrolled actual emissions of one tons per year or more of any individual criteria pollutant (pollutants are not summed) for which the area is nonattainment. (Applicant is required to file an APEN since emissions exceed 1 ton per year VOC) Part B—Construction Permit Exemptions 002,003 Applicant is required to obtain a permit since uncontrolled VOC emissions from this facility are greater than the 2.0 TPY threshold(Reg. 3, Part B, Section II.D.3.a) Regulation 6 -New Source Performance Standards 002 NSPS Kb: Not subject because tanks are <19,800 gallons 003 None Regulation 7—Volatile Organic Compounds 002 Tanks store crude oil; Reg 7 does not apply Page 3 003 None Reaulation 8—Hazardous Air Pollutants 002 MACT EEEE: Not subject because tanks are located at a minor source 002 MACT HH: Not subject because tanks are located at a minor source 003 None Section 13—Aerometric Information Retrieval System Coding Information Emission Pollutant/ Fugitive Emission Factor Control Point Process Process Description Factor CAS# (Y/N) Source (%) 128 lb/1000 gal VOC No E&P TANK 95 throughput E&P Condensate 0.26 Benzene/ 01 Storage Tanks lb/1000 gal 71432 No E&P TANK 95 002 throughput 1.5 n-Hexane/ lb/1000 gal 110543 No E&P TANK 95 throughput SCC 40400311 —Fixed Roof Tank, Condensate,working+breathing+flashing losses Point Process Process Description Emission Pollutant/ Fugitive Emission Factor Control Factor CAS# (Y/N) Source (%) 6.24 lb/1000 CDPHE PS gallons VOC No Memo 09-02 95 throughput Produced Water Storage 0.17 lb/1000 CDPHE PS 01 Tanks gallons Benzene No Memo 09-02 95 003 throughput 0.52 lb/1000 CDPHE PS gallons n-Hexane No Memo 09-02 95 throughput SCC 40400315—Fixed Roof Tank, Produced Water,working+breathing+flashing losses Section 14—Miscellaneous Application Notes AIRS Point 003 Produced Water Storage Tanks State-Developed Emission factors are: Produced Water Tank Default County Emission Factors(lb/bbl) VOC Benzene n-Hexane Adams,Arapahoe, Boulder, Broomfield, Denver, 0.262 0.007 0.022 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 0.178 0.004 0.010 Remainder of Colorado 0.262 0.007 0.022 State-Developed Emission factors in lb/1000 gal are: Produced Water Tank Default County Emission Factors (lb/1000 gal) VOC Benzene n-Hexane Adams, Arapahoe, Boulder, Broomfield, Denver, 6.2381 0.1667 0.5238 Douglas, Jefferson, Larimer and Weld Garfield, Mesa, Rio Blanco and Moffat 4.2381 0.0952 0.2381 Remainder of Colorado - 6.2381 0.1667 0.5238 Page 4 Summary of Preliminary Analysis - NG RICE Company Name Continental Resources, Inc. Permit No. 13WE2929 Facility Name Wallach 1-8H AIRS 123/9C04/001 Facility Location Section 8, T7N, R61W Review Date 01/15/2014 Facility Equipment ID NA Permit Engineer Peter Armington Requested Action New permit/newly reported emission Issuance No. 1 Emission Point Description One(1) Caterpillar, Model G3306, Serial Number R6S00565, natural gas-fired, naturally aspirated,4SRB reciprocating internal combustion engine, site rated at 145 horsepower at 1800 RPM. This engine shall be equipped with a non-selective catalytic reduction (NSCR) system and air-fuel ratio control. This emission unit is used for natural gas compression. Natural Gas Consumption Requested (mmscf/yr) 10.21 Requested(mmscf/m) 0.87 Fuel Heat Value(btu/scf) 1020 BSCF (Btu/hp-hr) 8200 Emission Factor Sources Uncontrolled Controlled NOx Email from Great Plains Gas Compression Email from Great Plains Gas Compression VOC Email from Great Plains Gas Compression Email from Great Plains Gas Compression CO Email from Great Plains Gas Compression Email from Great Plains Gas Compression Formaldehyde AP-42,Table 3.2-3(7/2000),Natural Gas 0 SOX AP-42;Table 3.2-3(7/2000),Natural Gas No Control TSP AP-42;Table 3.2-3(7/2000),Natural Gas No Control PM10 AP-42;Table 3.2-3(7/2000),Natural Gas No Control PM2.5 AP-42;Table 3.2-3(7/2000),Natural Gas No Control Other Pollutants Point Summary of Criteria Emissions (tpy) Uncontrolled Controlled Proposed Control Requested Requested PTE Efficiency NOx 15.3 1.4 15.3 90.8% VOC 3.1 0.7 3.1 77.3% CO 18.3 1.4 18.3 92.4% SOx 0.0 0.0 0.0 0.0% TSP 0.1 0.1 0.1 0.0% PM10 0.1 0.1 0.1 0.0% PM2.5 0.1 0.1 0.1 0.0% Total HAPs* 0.0 0.0 0.2 0.0% *Uncontrolled requested and controlled requested totals include HAPs only if the uncontrolled actual values are above de minimus thresholds. PTE includes all HAPs calculated, even those below de minimus. Point Summary of Hazardous Air Pollutants Ib/yr) Uncontrolled Controlled Proposed Control HAP Name Requested Requested PTE Efficiency Formaldehyde 214 214 214 0.0% Methanol * 32 0.0% Acetaldehyde * * 29 0.0% Acrolein * 27 0.0% Benzene * 16 0.0% 1,3-Butadiene * * 7 0.0% Toluene * * 6 0.0% *Uncontrolled requested and controlled requested values are shown only for pollutants where REQUESTED UNCONTROLLED is greater than de minimus Permitting Requirements Ambient Air Impacts Source is not required to model based on Division Guidelines Public Comment Public Comment Required MACT 777Z Missing or invalid entry information less than or equal to 500 HP located at a(n)Area Source Reg 7 XVII.E NOx: NA CO: NA VOC: NA Standards(g/hp-hr) Reg 7 XVI.B(Ozone NAA No requirements)applies? MACT ZZZZ(area source) Is this engine subject to MACT ZZZZ area Yes source requirements? Is this engine subject to NSPS JJJJ? Yes NSPS JJJJ Note: JJJJ requriements are not currently included as permit conditions because the reg has not been adopted into Reg 6. Comments/Notes 0 This facility is a Synthetic Minor source for Title V, NSR, and/or MACT applicability. GP02 Info: This facility is a True Minor source of NOX and/or CO for Title V. True Minor source of formaldehyde for Title V. No stack testing required. Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Division Information Engineer. Peter Armington Attainment Status Control Engineer: Stefanie Rucker PM10 Attainment Review Date: 01/15/2014 PM2.5 Attainment Application Date: 09/26/2013 SOx Attainment NOx Nonattainmen VOC Nonattainmen Facility Information CO Attainment Permit No. 13WE2929 County# 123 Weld AIRs Facility# 9C04 Point# 004 Facility Equipment ID Separator&Treater Gas Company Name: Continental Resources, In c Source Name: Wallach 1-8H Section 8 T7N R61 Source Location: W SIC: 1311 Elevation(feet) 4947 New Permit Modification APEN X (CP1) (Issuance#) Required/Permit Fxemnt Transfer of APEN Ownership Exempt/Permit Fxemnt Notes Equipment Description This source vents natural gas from: a well head separator Emissions from this source are: routed to an enclosed flare Natural gas venting from a well head separator.Emissions from this source are routed to an enclosed flare. 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-mop at 60F and 1 atm Throughput(0) 12 MMscf/yr 1383.6 scf/hr 1.03 MMscf/mo MW 26.000 Ib/Ib-mol I 0.000 MMscf/d mole% MW Ibx/Ibmol mass fraction E lb/hr lb/yr tpy Helium 0 4.0026 0.000 0.000 Helium 0.0 0 0.00 CO2 1.477 44.01 0.650 0.025 CO2 2.4 20787 10.39 N2 2.177 28.013 0.610 0.023 N2 2.2 19502 9.75 methane 69 085 16.041 11.082 0.426 methane 40.5 354388 177.19 ethane 11.835 30.063 3.558 0.137 ethane 13.0 113779 56.89 propane 8 53 44.092 3.7610 0.145 propane 13.7 120274 60.14 isobutane 0 571 58.118 0.3319 0.013 isobutane 1.2 10612 5.31 n-butane 2.982 58.118 1./331 U.06/ n-butane 6.3 55422 21./1 isopentane 0.948 72.114 0.6836 0.026 isopentane 2.5 21862 10.93 n-pentane 0.172 72.114 0.1240 0 00 n-pentane 0.5 3967 1.98 cyclopentane 0 70.13 0.0000 0.000 cyclopentane 0.0 0 0.00 n-Hexane 0 2520 86.18 0.2172 0.008 n-Hexane 0.8 6945 3.47 cyclohexane 0.0000 84.16 0.0000 0.000 cyclohexane 0.0 0 0.00 Other hexanes 0.034 86.18 0.0293 0.001 Other hexanes 0.1 937 0.47 heptanes 0 119 100.21 0.1192 0.005 heptanes 0.4 3813 1.91 methylcyclohexane 0 98.19 0.0000 0.000 methylcyclohexane 0.0 0 0.00 224-TMP 0 114.23 0.0000 0.000 224-TMP 0.0 0 0.00 Benzene 0.073 78.12 0.0570 0.002 Benzene 0.2 1824 0.91 Toluene 0 141 92.15 0.1299 0.005 Toluene 0.5 4155 2.08 Ethylbenzene 0.099 106.17 0.1051 0.004 Ethylbenzene 0.4 3361 1.68 Xylenes 0.233 106.17 0.2474 0.010 Xylenes 0.9 7911 3.96 Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division IC8+Heavies I 0 3951 648 4621 2.5614 r 0.099 IC8+Heavies I 9.4 1 81911 40.96 VOC mass fraction: 0.3885 Total VOC Emissions(Uncontrolled) 161.5 26.000 annual limit assuming 95%control 8.1 Notes monthly limit assuming 95%control(lb/rno.) 1371.6 Mole%,MW.and mass fractions from Wallach 1-8H gas analysis Emissions are based on 8760 hours of operation per year I calculated the average MW of C8+based on the average MW on the analysis for the gas Produced Natural Gas Venting/Flaring Preliminary Analysis Colorado Department of Public Health and Environment Air Pollution Control Division Flaring Information Equipment Description Flare to combust produced gas until pipeline is available at this wellhead facility Manufacturer Steffes Model Serial Number Gas Heating Value 1331 Btu/scf Throughput 16131 72 MMBtu/yr Combustion emission factor source: AP-42. Chapter 13 5 0.068 lb NOX/MMBtu 0.37 lb CO/MMBtu 0.55 tpy NOX 2.98 tpy CO j Emissions Summary 0.55 tpy NOX Uncontrolled/PTE 2.98 tpy CO 161.497 tpy VOC Controlled 8.075 tpy VOC Uncontrolled Scenario A Controlled Total(Ib/yr) Bin Reportable? Total(Ib/yr) Benzene 1824 A Yes 91 Toluene 4155 C Yes 208 Ethylbenzene 3361 C Yes 168 Xylenes 7911 C Yes 396 n-hexane 6945 C Yes 347 224-TMP 0 C No 0 Regulatory Applicability AQCC Regulation 1 This source m 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 307A opacity' AQCC Regulation 2 Section I.A applies to all emission sources. "No person,wherever located,shall cause or allow the emission of odorous air contaminants from any single source such as to result in detectable odors which are measured in excess of the following limits: For areas used predominantly for residential or commercial purposes it is a violation if odors are detected after the odorous air has been diluted with seven(7)or more volumes of odor free air." AQCC Regulation 3 An APEN is required for this source because uncontroaed VOC emissions Part A: exceed one ton per year in a nonattainment area for ozone A permit is required for this source because uncontrolled VOC emissions from this facility exceed two tons per year in a nonattainment area for ozone. Part B. This source is subject to Section III D.2(Minor Source RACT)because it is located in a nonattainment area. RACT for this source has been determined to be the use of a flare to control emissions. Is public comment Public Comment Required required? Facility Status This facility is a synthetic minor source of VOC for Title V applicability This facility is a synthetic minor source of VOC for NANSR applicability ... .J L C E R 7 J ' E1 a C — N I u C ._+ c — C1 N 0'l.Ci C L *3 c i a. I L c ' ' T •f. 3 IZI ?^ . ❑ C L. 7 L E f^.- rte: �' �^ v O / C' 1'- y C G C N O �A o a, o a 2. ., o; o w "�1 c. c c a 00 n-.40 E y �� O E G G r_ C 0 C VI ~ kCj LoL,y� .°C ai l Fc c L L C L . C E R C �• a L 0 bill % 1. )I 31 G O M 6! h E Y �5$f C ~ C f C L E S �I C To U tJ a C 9 Y "` O o J O .c - y • �' i ..� E 17 O S J w U G •0 7 r ' v t Z' O 1 F- O 3 .•O 2 C o. C �. ,- E ` ` .V. r ▪ L ' 'v 7 C C v E ." U v o c �. ° c c. as a �• . '' a4 i,,4- .p00 y a .. , r w e te o e �- E fi ° v0 c c 7 3I c c E. _ Li E lc u ! E a — $ , u 7 N n.i — a a Q oo d c ? v t. i e �^ `m C GI c Q C _,C en _ S C O R L �. C r r R Wf 0.a .. i. C C C y Y S � .�' t. L •�.�+ 1L G Irp' co >, N ❑ ❑ Y V Y C Y J •? y CL E y Q L ~ .I. i. 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O Cp L c0 C/) r p CC � Q) E v �, ¢ a c -a E E co , rn O Oa. aw Q" a f CC G0I- z ° Air Pollutant Emission Notice(APEN)-and- Application for Construction Permit Oil.AND GAS EXPLORATION AND PRODUCTION CONDENSATE STORAGE TANK BATTERY Current Status(Cheek all thin app�ly) Reason for API-:N Submittal(Check all that apply) AIRS ID#': ..._..__1 3 - -(_co.( `0 oz. ❑ APEN update only' ® New or previously unreported battery ❑ Modification to existing source` SEP 2e, Ai) 0 Previously grandfathered batten= 0 Registration ter coverage under general permit no.CiP01 ❑ Synthetic minor facility &cancellation request for individual permit`': O Located in the K-hr Ozone Control Area 0 Application for or Modification of an individual permit O Registered under general permit no.GPO! t, ....11,,. 0 Administrative permit amendment' 'V 1• ❑ Permitted under individual permit: 13 O Other: For iodic idual permit applications.check il'you wane- ®A copy of the preliminary analysis conducted by the Division E 1 u review a draft of the permit prior to issuance Company Name": Continental Resources. Inc. —_ O(iCC Operator a: 10347 Mailing Address": PO Box 1389 --- --- _ told.sencscal l:a clr.co City: Gi,endivc State: Mil Zip: 59330 E-mail: in Contact Name; (odd Senescall ('hone: (406)911-2529 Fax: (701)76.3-6704 Tank Battery Name'•: Wallach 1-811 Number of tanks: 3 Location'`(QQ See. fwp. Range.): Sec K. 17N,R61W County: Weld Total tank capacity lbbli: L200(400 ea) Calendar year for which"Actual"data applies": Year(s)tank(s)were placed in senice": 2013 Control Description' : Stel1es Engineered Flare Control Efficiency ': 95% Condensate Throughput''Ihhl:yearI Requested": 18.738 Maximum tier PTY.calculation": Actual'": While Controls Operational'' Other equipment at facility": heater treater.separator,produced\1met tank.engine These arc crude oil tanks and the API Gravity is•-40.therefore,the tanks don't qualify for(H8 coverage. Individual permit is Comments: requested. Estimated emissions at throughputs listed above. Use X<4 far requested throughput/emission values unless requesting an individual permit ❑Check if the Division is to calculate emissions. ®('heck if site-specific emission factors provided to calculate emissions'''. Emission Factor Battery. Requested Emissions's Actual Emissions"' I'ollutant2' llh'hhl l PTE=I c l:ncontrolleul='' Controlled'' Uncontrolled'° Control led'-' VO('lions/yearI 5.148 48.23? 2.412 — — NOx Itons""y ear) . CO l ions/}earl — Iieniene IIhs'yearl 0.010247 192 10 n-I lexanc 1lhs-yearf O.(K,0(,25 1136 56 Wells serviced by this tank or tank battery'' :API#: 0512336841 Name: Wallach I-81( ®Newly Reported Welt API ti: Name: ❑Newly Reported Well API 4: - Name: — 0 Newly Reported Well API v: _ Name: 0 Newly Reported Well API#: Name — 0 Newly Reported Well API 5: Name -- --- 0 Newly Reported Well API 5: Name: _ 0 Newly Reported Well the signature below indicates that I have knowledge of the facts herein set Forth and that the same are true,accurate.and complete to the hest of my knowledge and belief If this is a registration for coverage under general permit(iP0 I.I further certify that this source is and will be operated in full compliance with each condition of general permit(iP01. -----<17— aJ.;* -- — - '7 1-r z (71? Signature of I.cgall) Authorized Person(not a vendor or consultant) Date fudd Senescall Senior Environmental Specialist Type or Print Name of Person Signing Above — Official Title Submit this form.along V4 ill,5152.90 for each Colorado Department of Public I lealth and I'n%ironment For information call: tiling of up to 5 tank hatter) AI'f:NS. Include Air Pollution Control Division.A1'CD-SS-lit Q Q (303)692-3150 $250 General Permit fee tier each new(i1' 4300 Cherry Creek Drive South "`� O"9 Gnnn1 4nr'n -nc 1 Page 1 of 1 Contincntal.Wallach.l-KIt.FormAP('I)-205.1{&PCrudc4)irlankApf•:\ i r I Co T, — a .0 t >. N C o a) 0 CO . N Q L 2 g Cl) c y �, 0 0 .E f o o o w o Z U N W a a 0 N N u T CO O a m a '0 -0 Q �; .� y ao O Q- rN >. 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